In situ thermal processing of a coal formation to control product composition

ABSTRACT

A coal formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H 2 , and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat and pressure applied to the formation may be controlled so that a majority of the hydrocarbons produced from the formation have carbon numbers less than 25. Conditions may be controlled to produce low quantities of olefins in condensable hydrocarbons produced from the formation and low quantities of olefins in non-condensable hydrocarbons produced from the formation.

PRIORITY CLAIM

[0001] This application claims priority to U.S. Provisional ApplicationNo. 60/199,215 entitled “In Situ Energy Recovery,” filed Apr. 24, 2000,U.S. Provisional Application No. 60/199,214 entitled “In Situ EnergyRecovery From Coal,” filed Apr. 24, 2000, and U.S. ProvisionalApplication No. 60/199,213 entitled “Emissionless Energy Recovery FromCoal,” filed Apr. 24, 2000. The above-referenced provisionalapplications are hereby incorporated by reference as if fully set forthherein.

BACKGROUND OF THE INVENTION

[0002] 1. Field of the Invention

[0003] The present invention relates generally to methods and systemsfor production of hydrocarbons, hydrogen, and/or other products fromcoal formations. Certain embodiments relate to in situ conversion ofhydrocarbons to produce hydrocarbons, hydrogen, and/or novel productstreams from underground coal formations.

[0004] 2. Description of Related Art

[0005] Hydrocarbons obtained from subterranean (e.g., sedimentary)formations are often used as energy resources, as feedstocks, and asconsumer products. Concerns over depletion of available hydrocarbonresources have led to development of processes for more efficientrecovery, processing and/or use of available hydrocarbon resources, forexample coal. In situ processes for coal formations may be used toremove hydrocarbon materials from subterranean formations. Chemicaland/or physical properties of coal within a subterranean formation mayneed to be changed to allow coal to be more easily removed from thesubterranean formation. The chemical and physical changes may include insitu reactions that produce removable fluids, composition changes,solubility changes, phase changes, and/or viscosity changes of thehydrocarbon material within the formation. A fluid may be, but is notlimited to, a gas, a liquid, an emulsion, a slurry and/or a stream ofsolid particles that has flow characteristics similar to liquid flow.

[0006] Examples of in situ processes utilizing downhole heaters areillustrated in U.S. Pat. No. 2,634,961 to Ljungstrom, U.S. Pat. No.2,732,195 to Ljungstrom, U.S. Pat. No. 2,780,450 to Ljungstrom, U.S.Pat. No. 2,789,805 to Ljungstrom, U.S. Pat. No. 2,923,535 issued toLjungstrom, and U.S. Pat. No. 4,886,118 to Van Meurs et al., each ofwhich is incorporated by reference as if fully set forth herein.

[0007] A heat source may be used to heat a subterranean formation.Electrical heaters may be used to heat the subterranean formation byradiation and/or conduction. An electrical heater may resistively heatan element. U.S. Pat. No. 2,548,360 to Germain, which is incorporated byreference as if fully set forth herein, describes an electrical heatingelement placed within a viscous oil within a wellbore. The heaterelement heats and thins the oil to allow the oil to be pumped from thewellbore. U.S. Pat. No. 4,716,960 to Eastlund et al., which isincorporated by reference as if fully set forth herein, describeselectrically heating tubing of a petroleum well by passing a relativelylow voltage current through the tubing to prevent formation of solids.U.S. Pat. No. 5,065,818 to Van Egmond, which is incorporated byreference as if fully set forth herein, describes an electrical heatingelement that is cemented into a well borehole without a casingsurrounding the heating element.

[0008] U.S. Pat. No. 6,023,554 to Vinegar et al., which is incorporatedby reference as if fully set forth herein, describes an electricalheating element that is positioned within a casing. The heating elementgenerates radiant energy that heats the casing. A granular solid fillmaterial may be placed between the casing and the formation. The casingmay conductively heat the fill material, which in turn conductivelyheats the formation.

[0009] U.S. Pat. No. 4,570,715 to Van Meurs et al., which isincorporated by reference as if fully set forth herein, describes anelectrical heating element. The heating element has an electricallyconductive core, a surrounding layer of insulating material, and asurrounding metallic sheath. The conductive core may have a relativelylow resistance at high temperatures The insulating material may haveelectrical resistance, compressive strength and heat conductivityproperties that are relatively high at high temperatures. The insulatinglayer may inhibit arcing from the core to the metallic sheath. Themetallic sheath may have tensile strength and creep resistanceproperties that are relatively high at high temperatures.

[0010] U.S. Pat. No. 5,060,287 to Van Egmond, which is incorporated byreference as if fully set forth herein, describes an electrical heatingelement having a copper-nickel alloy core.

[0011] Combustion of a fuel may be used to heat a formation. Combustinga fuel to heat a formation may be more economical than using electricityto heat a formation. Several different types of heaters may use fuelcombustion as a heat source that heats a formation. The combustion maytake place in the formation, in a well and/or near the surface.Combustion in the formation may be a fireflood. An oxidizer may bepumped into the formation. The oxidizer may be ignited to advance a firefront towards a production well. Oxidizer pumped into the formation mayflow through the formation along fracture lines in the formation.Ignition of the oxidizer may not result in the fire front flowinguniformly through the formation.

[0012] A flameless combustor may be used to combust a fuel within awell. U.S. Pat. No. 5,255,742 to Mikus, U.S. Pat. No. 5,404,952 toVinegar et al., U.S. Pat. No. 5,862,858 to Wellington et al., and U.S.Pat. No 5,899,269 to Wellington et al., which are incorporated byreference as if fully set forth herein, describe flameless combustors.Flameless combustion may be accomplished by preheating a fuel andcombustion air to a temperature above an auto-ignition temperature ofthe mixture. The fuel and combustion air may be mixed in a heating zoneto combust. In the heating zone of the flameless combustor, a catalyticsurface may be provided to lower the auto-ignition temperature of thefuel and air mixture.

[0013] Heat may be supplied to a formation from a surface heater. Thesurface heater may produce combustion gases that are circulated throughwellbores to heat the formation. Alternately, a surface burner may beused to heat a heat transfer fluid that is passed through a wellbore toheat the formation. Examples of fired heaters, or surface burners thatmay be used to heat a subterranean formation, are illustrated in U.S.Pat. No. 6,056,057 to Vinegar et al. and U.S. Pat. No. 6,079,499 toMikus et al., which are both incorporated by reference as if fully setforth herein.

[0014] Coal is often mined and used as a fuel within an electricitygenerating power plant. Most coal that is used as a fuel to generateelectricity is mined. A significant number of coal formations are,however, not suitable for economical mining. For example, mining coalfrom steeply dipping coal seams, from relatively thin coal seams (e.g.,less than about 1 meter thick), and/or from deep coal seams may not beeconomically feasible. Deep coal seams include coal seams that are at,or extend to, depths of greater than about 3000 feet (about 914 m) belowsurface level. The energy conversion efficiency of burning coal togenerate electricity is relatively low, as compared to fuels such asnatural gas. Also, burning coal to generate electricity often generatessignificant amounts of carbon dioxide, oxides of sulfur, and oxides ofnitrogen that are released into the atmosphere.

[0015] Synthesis gas may be produced in reactors or in situ within asubterranean formation. Synthesis gas may be produced within a reactorby partially oxidizing methane with oxygen. In situ production ofsynthesis gas may be economically desirable to avoid the expense ofbuilding, operating, and maintaining a surface synthesis gas productionfacility. U.S. Pat. No. 4,250,230 to Terry, which is incorporated byreference as if fully set forth herein, describes a system for in situgasification of coal. A subterranean coal seam is burned from a firstwell towards a production well. Methane, hydrocarbons, H₂, CO, and otherfluids may be removed from the formation through the production well.The H₂ and CO may be separated from the remaining fluid. The H₂ and COmay be sent to fuel cells to generate electricity.

[0016] U.S. Pat. No. 4,057,293 to Garrett, which is incorporated byreference as if fully set forth herein, discloses a process forproducing synthesis gas. A portion of a rubble pile is burned to heatthe rubble pile to a temperature that generates liquid and gaseoushydrocarbons by pyrolysis. After pyrolysis, the rubble is furtherheated, and steam or steam and air are introduced to the rubble pile togenerate synthesis gas.

[0017] U.S. Pat. No. 5,554,453 to Steinfeld et al., which isincorporated by reference as if fully set forth herein, describes an exsitu coal gasifier that supplies fuel gas to a fuel cell. The fuel cellproduces electricity. A catalytic burner is used to burn exhaust gasfrom the fuel cell with an oxidant gas to generate heat in the gasifier.

[0018] Carbon dioxide may be produced from combustion of fuel and frommany chemical processes. Carbon dioxide may be used for variouspurposes, such as, but not limited to, a feed stream for a dry iceproduction facility, supercritical fluid in a low temperaturesupercritical fluid process, a flooding agent for coal beddemethanation, and a flooding agent for enhanced oil recovery. Althoughsome carbon dioxide is productively used, many tons of carbon dioxideare vented to the atmosphere.

[0019] As outlined above, there has been a significant amount of effortto develop methods and systems to economically produce hydrocarbons,hydrogen, and/or other products from coal formations. At present,however, there are still many coal formations from which hydrocarbons,hydrogen, and/or other products cannot be economically produced. Thus,there is still a need for improved methods and systems for production ofhydrocarbons, hydrogen, and/or other products from various coalformations.

SUMMARY OF THE INVENTION

[0020] In an embodiment, hydrocarbons within a coal formation may beconverted in situ within the formation to yield a mixture of relativelyhigh quality hydrocarbon products, hydrogen, and other products. One ormore heat sources may be used to heat a portion of the coal formation totemperatures that allow pyrolysis of the hydrocarbons. Hydrocarbons,hydrogen, and other formation fluids may be removed from the formationthrough one or more production wells. The formation fluids may beremoved in a vapor phase. Temperature and pressure in at least a portionof the formation may be controlled during pyrolysis to yield improvedproducts from the formation.

[0021] A heated formation may also be used to produce synthesis gas. Incertain embodiments synthesis gas is produced after production ofpyrolysis fluids.

[0022] A formation may be heated to a temperature greater than 400° C.prior to contacting a synthesis gas generating fluid with the formation.Contacting a synthesis gas generating fluid, such as water, steam,and/or carbon dioxide, with carbon and/or hydrocarbons within theformation results in generation of synthesis gas if the temperature ofthe carbon is sufficiently high. Synthesis gas generation is, in someembodiments, an endothermic process. Additional heat may be added to theformation during synthesis gas generation to maintain a high temperaturewithin the formation. The heat may be added from heater wells and/orfrom oxidizing carbon and/or hydrocarbons within the formation. Thegenerated synthesis gas may be removed from the formation through one ormore production wells.

[0023] After production of pyrolysis fluids and/or synthesis gas, fluidmay be sequestered within the formation. To store a significant amountof fluid within the formation, a temperature of the formation will oftenneed to be less than about 100° C. Water may be introduced into at leasta portion of the formation to generate steam and reduce a temperature ofthe formation. The steam may be removed from the formation. The steammay be utilized for various purposes, including, but not limited to,heating another portion of the formation, generating synthesis gas in anadjacent portion of the formation, generating electricity, and/or as asteam flood in a oil reservoir. After the formation is cooled, fluid(e.g., carbon dioxide) may be pressurized and sequestered in theformation. Sequestering fluid within the formation may result in asignificant reduction or elimination of fluid that is released to theenvironment due to operation of the in situ conversion process.

[0024] In an embodiment, one or more heat sources may be installed intoa formation to heat the formation. Heat sources may be installed bydrilling openings (well bores) into the formation. In some embodimentsopenings may be formed in the formation using a drill with a steerablemotor and an accelerometer. Alternatively, an opening may be formed intothe formation by geosteered drilling. Alternately, an opening may beformed into the formation by sonic drilling.

[0025] One or more heat sources may be disposed within the opening suchthat the heat source may be configured to transfer heat to theformation. For example, a heat source may be placed in an open wellborein the formation. In this manner, heat may conductively and radiativelytransfer from the heat source to the formation. Alternatively, a heatsource may be placed within a heater well that may be packed withgravel, sand, and/or cement. The cement may be a refractory cement.

[0026] In some embodiments one or more heat sources may be placed in apattern within the formation. For example, in one embodiment, an in situconversion process for coal may include heating at least a portion of acoal formation with an array of heat sources disposed within theformation. In some embodiments, the array of heat sources can bepositioned substantially equidistant from a production well. Certainpatterns (e.g., triangular arrays, hexagonal arrays, or other arraypatterns) may be more desirable for specific applications. In addition,the array of heat sources may be disposed such that a distance betweeneach heat source may be less than about 70 feet (21 m). In addition, thein situ conversion process for hydrocarbons may include heating at leasta portion of the formation with heat sources disposed substantiallyparallel to a boundary of the hydrocarbons. Regardless of thearrangement of or distance between the heat sources, in certainembodiments, a ratio of heat sources to production wells disposed withina formation may be greater than about 5, 8, 10, 20, or more.

[0027] Certain embodiments may also include allowing heat to transferfrom one or more of the heat sources to a selected section of the heatedportion. In an embodiment, the selected section may be disposed betweenone or more heat sources. For example, the in situ conversion processmay also include allowing heat to transfer from one or more heat sourcesto a selected section of the formation such that heat from one or moreof the heat sources pyrolyzes at least some hydrocarbons within theselected section. In this manner, the in situ conversion process mayinclude heating at least a portion of a coal formation above apyrolyzation temperature of hydrocarbons in the formation. For example,a pyrolyzation temperature may include a temperature of at least about270° C. Heat may be allowed to transfer from one or more of the heatsources to the selected section substantially by conduction.

[0028] One or more heat sources may be located within the formation suchthat superposition of heat produced from one or more heat sources mayoccur. Superposition of heat may increase a temperature of the selectedsection to a temperature sufficient for pyrolysis of at least some ofthe hydrocarbons within the selected section. Superposition of heat mayvary depending on, for example, a spacing between heat sources. Thespacing between heat sources may be selected to optimize heating of thesection selected for treatment. Therefore, hydrocarbons may be pyrolyzedwithin a larger area of the portion. In this manner, spacing betweenheat sources may be selected to increase the effectiveness of the heatsources, thereby increasing the economic viability of a selected in situconversion process for hydrocarbons. Superposition of heat tends toincrease the uniformity of heat distribution in the section of theformation selected for treatment.

[0029] Various systems and methods may be used to provide heat sources.In an embodiment, a natural distributed combustor system and method maybe configured to heat at least a portion of a coal formation. The systemand method may first include heating a first portion of the formation toa temperature sufficient to support oxidation of at least some of thehydrocarbons therein. One or more conduits may be disposed within one ormore openings. One or more of the conduits may be configured to providean oxidizing fluid from an oxidizing fluid source into an opening in theformation. The oxidizing fluid may oxidize at least a portion of thehydrocarbons at a reaction zone within the formation. Oxidation maygenerate heat at the reaction zone. The generated heat may transfer fromthe reaction zone to a pyrolysis zone in the formation. The heat maytransfer by conduction, radiation, and/or convection. In this manner, aheated portion of the formation may include the reaction zone and thepyrolysis zone. The heated portion may also be located substantiallyadjacent to the opening. One or more of the conduits may also beconfigured to remove one or more oxidation products from the reactionzone and/or formation. Alternatively, additional conduits may beconfigured to remove one or more oxidation products from the reactionzone and/or formation.

[0030] In an embodiment, a system and method configured to heat a coalformation may include one or more insulated conductors disposed in oneor more openings in the formation. The openings may be uncased.Alternatively, the openings may include a casing. As such, the insulatedconductors may provide conductive, radiant, or convective heat to atleast a portion of the formation. In addition, the system and method maybe configured to allow heat to transfer from the insulated conductor toa section of the formation. In some embodiments, the insulated conductormay include a copper-nickel alloy. In some embodiments, the insulatedconductor may be electrically coupled to two additional insulatedconductors in a 3-phase Y configuration.

[0031] In an embodiment, a system and method may include one or moreelongated members disposed in an opening in the formation. Each of theelongated members may be configured to provide heat to at least aportion of the formation. One or more conduits may be disposed in theopening. One or more of the conduits may be configured to provide anoxidizing fluid from an oxidizing fluid source into the opening. Incertain embodiments, the oxidizing fluid may be configured tosubstantially inhibit carbon deposition on or proximate to the elongatedmember.

[0032] In an embodiment, a system and method for heating a coalformation may include oxidizing a fuel fluid in a heater. The method mayfurther include providing at least a portion of the oxidized fuel fluidinto a conduit disposed in an opening in the formation. In addition,additional heat may be transferred from an electric heater disposed inthe opening to the section of the formation. Heat may be allowed totransfer substantially uniformly along a length of the opening.

[0033] Energy input costs may be reduced in some embodiments of systemsand methods described above. For example, an energy input cost may bereduced by heating a portion of a coal formation by oxidation incombination with heating the portion of the formation by an electricheater. The electric heater may be turned down and/or off when theoxidation reaction begins to provide sufficient heat to the formation.In this manner, electrical energy costs associated with heating at leasta portion of a formation with an electric heater may be reduced. Thus, amore economical process may be provided for heating a coal formation incomparison to heating by a conventional method. In addition, theoxidation reaction may be propagated slowly through a greater portion ofthe formation such that fewer heat sources may be required to heat sucha greater portion in comparison to heating by a conventional method.

[0034] Certain embodiments as described herein may provide a lower costsystem and method for heating a coal formation. For example, certainembodiments may provide substantially uniform heat transfer along alength of a heater. Such a length of a heater may be greater than about300 m or possibly greater than about 600 m. In addition, in certainembodiments, heat may be provided to the formation more efficiently byradiation. Furthermore, certain embodiments of systems as describedherein may have a substantially longer lifetime than presently availablesystems.

[0035] In an embodiment, an in situ conversion system and method forhydrocarbons may include maintaining a portion of the formation in asubstantially unheated condition. In this manner, the portion mayprovide structural strength to the formation and/orconfinement/isolation to certain regions of the formation. A processedcoal formation may have alternating heated and substantially unheatedportions arranged in a pattern that may, in some embodiments, resemble acheckerboard pattern, or a pattern of alternating areas (e.g., strips)of heated and unheated portions.

[0036] In an embodiment, a heat source may advantageously heat onlyalong a selected portion or selected portions of a length of the heater.For example, a formation may include several coal layers. One or more ofthe coal layers may be separated by layers containing little and/or nocoal. A heat source may include several discrete high heating zones thatmay be separated by low heating zones. The high heating zones may bedisposed proximate coal layers such that the layers may be heated. Thelow heating zones may be disposed proximate to layers containing littleor no hydrocarbons such that the layers may not be substantially heated.For example, an electrical heater may include one or more low resistanceheater sections and one or more high resistance heater sections. In thismanner, low resistance heater sections of the electrical heater may bedisposed in and/or proximate to layers containing little or nohydrocarbons. In addition, high resistance heater sections of theelectrical heater may be disposed proximate coal layers. In anadditional example, a fueled heater (e.g., surface burner) may includeinsulated sections. In this manner, insulated sections of the fueledheater may be placed proximate to or adjacent to layers containinglittle or no hydrocarbons. Alternately, a heater with distributed airand/or fuel may be configured such that little and/or no fuel may becombusted proximate to or adjacent to layers containing little or nohydrocarbons. Such a fueled heater may include flameless combustors andnatural distributed combustors.

[0037] In an embodiment, a heating rate of the formation may be slowlyraised through the pyrolysis temperature range. For example, an in situconversion process for coal may include heating at least a portion of acoal formation to raise an average temperature of the portion aboveabout 270° C. by a rate less than a selected amount (e.g., about 10° C.,5° C., 3° C., 1° C., 0.5° C., or 0.1° C.) per day. In a furtherembodiment, the portion may be heated such that an average temperatureof the selected section may be less than about 375° C. or, in someembodiments, less than about 400° C.

[0038] In an embodiment, a temperature of the portion may be monitoredthrough a test well disposed in a formation. For example, the test wellmay be positioned in a formation between a first heat source and asecond heat source. Certain systems and methods may include controllingthe heat from the first heat source and/or the second heat source toraise the monitored temperature at the test well at a rate of less thanabout a selected amount per day. In addition or alternatively, atemperature of the portion may be monitored at a production well. Inthis manner, an in situ conversion process for coal may includecontrolling the heat from the first heat source and/or the second heatsource to raise the monitored temperature at the production well at arate of less than a selected amount per day.

[0039] Certain embodiments may include heating a selected volume of acoal formation. Heat may be provided to the selected volume by providingpower to one or more heat sources. Power may be defined as heatingenergy per day provided to the selected volume. A power (Pwr) requiredto generate a heating rate (h, in units of, for example, ° C./day) in aselected volume (V) of a coal formation may be determined by thefollowing equation: Pwr=h*V*C_(v)*ρ_(B). In this equation, an averageheat capacity of the formation (C_(v)) and an average bulk density ofthe formation (ρ_(b)) may be estimated or determined using one or moresamples taken from the coal formation.

[0040] Certain embodiments may include raising and maintaining apressure in a coal formation. Pressure may be, for example, controlledwithin a range of about 2 bars absolute to about 20 bars absolute. Forexample, the process may include controlling a pressure within amajority of a selected section of a heated portion of the formation. Thecontrolled pressure may be above about 2 bars absolute during pyrolysis.In an alternate embodiment, an in situ conversion process for coal mayinclude raising and maintaining the pressure in the formation within arange of about 20 bars absolute to about 36 bars absolute.

[0041] In an embodiment, compositions and properties of formation fluidsproduced by an in situ conversion process for coal may vary dependingon, for example, conditions within a coal formation.

[0042] Certain embodiments may include controlling the heat provided toat least a portion of the formation such that production of lessdesirable products in the portion may be substantially inhibited.Controlling the heat provided to at least a portion of the formation mayalso increase the uniformity of permeability within the formation. Forexample, controlling the heating of the formation to inhibit productionof less desirable products may, in some embodiments, include controllingthe heating rate to less than a selected amount (e.g., 10° C., 5° C., 3°C., 1° C., 0.5° C., or 0.1° C.) per day.

[0043] Controlling pressure, heat and/or heating rates of a selectedsection in a formation may increase production of selected formationfluids. For example, the amount and/or rate of heating may be controlledto produce formation fluids having an American Petroleum Institute(“API”) gravity greater than about 25. Heat and/or pressure may becontrolled to inhibit production of olefins in the produced fluids.

[0044] Controlling formation conditions to control the pressure ofhydrogen in the produced fluid may result in improved qualities of theproduced fluids. In some embodiments it may be desirable to controlformation conditions so that the partial pressure of hydrogen in aproduced fluid is greater than about 0.5 bar absolute, as measured at aproduction well.

[0045] In an embodiment, operating conditions may be determined bymeasuring at least one property of the formation. At least the measuredproperties may be input into a computer executable program. At least oneproperty of formation fluids selected to be produced from the formationmay also be input into the computer executable program. The program maybe operable to determine a set of operating conditions from at least theone or more measured properties. The program may also be configured todetermine the set of operating conditions from at least one property ofthe selected formation fluids. In this manner, the determined set ofoperating conditions may be configured to increase production ofselected formation fluids from the formation.

[0046] Certain embodiments may include altering a composition offormation fluids produced from a coal formation by altering a locationof a production well with respect to a heater well. For example, aproduction well may be located with respect to a heater well such that anon-condensable gas fraction of produced hydrocarbon fluids may belarger than a condensable gas fraction of the produced hydrocarbonfluids.

[0047] Condensable hydrocarbons produced from the formation willtypically include paraffins, cycloalkanes, mono-aromatics, anddi-aromatics as major components. Such condensable hydrocarbons may alsoinclude other components such as tri-aromatics, etc.

[0048] In certain embodiments, a majority of the hydrocarbons inproduced fluid may have a carbon number of less than approximately 25.Alternatively, less than about 15 weight % of the hydrocarbons in thefluid may have a carbon number greater than approximately 25. In otherembodiments fluid produced may have a weight ratio of hydrocarbonshaving carbon numbers from 2 through 4, to methane, of greater thanapproximately 0.3. The non-condensable hydrocarbons may include, but isnot limited to, hydrocarbons having carbon numbers less than 5.

[0049] In certain embodiments, the API gravity of the hydrocarbons inproduced fluid may be approximately 20 or above (e.g., 25, 30, 35, 40,50, etc.). In certain embodiments, the hydrogen to carbon atomic ratioin produced fluid may be at least approximately 1.7 (e.g., 1.8, 1.9,etc.).

[0050] In certain embodiments, fluid produced from a formation mayinclude oxygenated hydrocarbons. In an example, the condensablehydrocarbons may include an amount of oxygenated hydrocarbons greaterthan about 5% by weight of the condensable hydrocarbons.

[0051] Condensable hydrocarbons of a produced fluid may also includeolefins. For example, the olefin content of the condensable hydrocarbonsmay be from about 0.1% by weight to about 15% by weight. Alternatively,the olefin content of the condensable hydrocarbons may be from about0.1% by weight to about 2.5% by weight or, in some embodiments less thanabout 5% by weight.

[0052] Non-condensable hydrocarbons of a produced fluid may also includeolefins. For example, the olefin content of the non-condensablehydrocarbons may be gauged using the ethene/ethane molar ratio. Incertain embodiments the ethene/ethane molar ratio may range from about0.001 to about 0.15.

[0053] Fluid produced from the formation may include aromatic compounds.For example, the condensable hydrocarbons may include an amount ofaromatic compounds greater than about 20% or about 25% by weight of thecondensable hydrocarbons. The condensable hydrocarbons may also includerelatively low amounts of compounds with more than two rings in them(e.g., tri-aromatics or above). For example, the condensablehydrocarbons may include less than about 1%, 2%, or about 5% by weightof tri-aromatics or above in the condensable hydrocarbons.

[0054] In particular, in certain embodiments asphaltenes (i.e., largemulti-ring aromatics that are substantially insoluble in hydrocarbons)make up less than about 0.1% by weight of the condensable hydrocarbons.For example, the condensable hydrocarbons may include an asphaltenecomponent of from about 0.0% by weight to about 0.1% by weight or, insome embodiments, less than about 0.3% by weight.

[0055] Condensable hydrocarbons of a produced fluid may also includerelatively large amounts of cycloalkanes. For example, the condensablehydrocarbons may include a cycloalkane component of up to 30% by weight(e.g., from about 5% by weight to about 30% by weight) of thecondensable hydrocarbons.

[0056] In certain embodiments, the condensable hydrocarbons of the fluidproduced from a formation may include compounds containing nitrogen. Forexample, less than about 1% by weight (when calculated on an elementalbasis) of the condensable hydrocarbons is nitrogen (e.g., typically thenitrogen is in nitrogen containing compounds such as pyridines, amines,amides, etc.).

[0057] In certain embodiments, the condensable hydrocarbons of the fluidproduced from a formation may include compounds containing oxygen. Incertain embodiments between about 5% and about 30% by weight of thecondensable hydrocarbons are typically oxygen containing compounds suchas phenols, substituted phenols, ketones, etc. In some instances certaincompounds containing oxygen (e.g., phenols) may be valuable and, assuch, may be economically separated from the produced fluid.

[0058] In certain embodiments, the condensable hydrocarbons of the fluidproduced from a formation may include compounds containing sulfur. Forexample, less than about 1% by weight (when calculated on an elementalbasis) of the condensable hydrocarbons is sulfur (e.g., typically thesulfur is in sulfur containing compounds such as thiophenes, mercaptans,etc.).

[0059] Furthermore, the fluid produced from the formation may includeammonia (typically the ammonia condenses with the water, if any,produced from the formation). For example, the fluid produced from theformation may in certain embodiments include about 0.05% or more byweight of ammonia. Certain formations may produce larger amounts ofammonia (e.g., up to about 10% by weight of the total fluid produced maybe ammonia).

[0060] Furthermore, a produced fluid from the formation may also includemolecular hydrogen (H₂), water, carbon dioxide, hydrogen sulfide, etc.For example, the fluid may include a H₂ content between about 10% toabout 80% by volume of the non-condensable hydrocarbons.

[0061] Certain embodiments may include heating to yield at least about15% by weight of a total organic carbon content of at least some of thecoal formation into formation fluids.

[0062] In an embodiment, an in situ conversion process for treating acoal formation may include providing heat to a section of the formationto yield greater than about 60% by weight of the potential hydrocarbonproducts and hydrogen, as measured by the Fischer Assay.

[0063] In certain embodiments, heating of the selected section of theformation may be controlled to pyrolyze at least about 20% by weight (orin some embodiments about 25% by weight) of the hydrocarbons within theselected section of the formation.

[0064] Certain embodiments may include providing a reducing agent to atleast a portion of the formation. A reducing agent provided to a portionof the formation during heating may increase production of selectedformation fluids. A reducing agent may include, but is not limited to,molecular hydrogen. For example, pyrolyzing at least some hydrocarbonsin a coal formation may include forming hydrocarbon fragments. Suchhydrocarbon fragments may react with each other and other compoundspresent in the formation. Reaction of these hydrocarbon fragments mayincrease production of olefin and aromatic compounds from the formation.Therefore, a reducing agent provided to the formation may react withhydrocarbon fragments to form selected products and/or inhibit theproduction of non-selected products.

[0065] In an embodiment, a hydrogenation reaction between a reducingagent provided to a coal formation and at least some of the hydrocarbonswithin the formation may generate heat. The generated heat may beallowed to transfer such that at least a portion of the formation may beheated. A reducing agent such as molecular hydrogen may also beautogenously generated within a portion of a coal formation during an insitu conversion process for coal. In this manner, the autogenouslygenerated molecular hydrogen may hydrogenate formation fluids within theformation. Allowing formation waters to contact hot carbon in the spentformation may generate molecular hydrogen. Cracking an injectedhydrocarbon fluid may also generate molecular hydrogen.

[0066] Certain embodiments may also include providing a fluid producedin a first portion of a coal formation to a second portion of theformation. In this manner, a fluid produced in a first portion of a coalformation may be used to produce a reducing environment in a secondportion of the formation. For example, molecular hydrogen generated in afirst portion of a formation may be provided to a second portion of theformation. Alternatively, at least a portion of formation fluidsproduced from a first portion of the formation may be provided to asecond portion of the formation to provide a reducing environment withinthe second portion. The second portion of the formation may be treatedaccording to any of the embodiments described herein.

[0067] Certain embodiments may include controlling heat provided to atleast a portion of the formation such that a thermal conductivity of theportion may be increased to greater than about 0.5 W/(m° C.) or, in someembodiments, greater than about 0.6 W/(m° C.).

[0068] In certain embodiments a mass of at least a portion of theformation may be reduced due, for example, to the production offormation fluids from the formation. As such, a permeability andporosity of at least a portion of the formation may increase. Inaddition, removing water during the heating may also increase thepermeability and porosity of at least a portion of the formation.

[0069] Certain embodiments may include increasing a permeability of atleast a portion of a coal formation to greater than about 0.01, 0.1, 1,10, 20 and/or 50 Darcy. In addition, certain embodiments may includesubstantially uniformly increasing a permeability of at least a portionof a coal formation. Some embodiments may include increasing a porosityof at least a portion of a coal formation substantially uniformly.

[0070] In certain embodiments, after pyrolysis of a portion of aformation, synthesis gas may be produced from carbon and/or hydrocarbonsremaining within the formation. Pyrolysis of the portion may produce arelatively high, substantially uniform permeability throughout theportion. Such a relatively high, substantially uniform permeability mayallow generation of synthesis gas from a significant portion of theformation at relatively low pressures. The portion may also have a largesurface area and/or surface area/volume. The large surface area mayallow synthesis gas producing reactions to be substantially atequilibrium conditions during synthesis gas generation. The relativelyhigh, substantially uniform permeability may result in a relatively highrecovery efficiency of synthesis gas, as compared to synthesis gasgeneration in a coal formation that has not been so treated.

[0071] Synthesis gas may be produced from the formation prior to orsubsequent to producing a formation fluid from the formation. Forexample, synthesis gas generation may be commenced before and/or afterformation fluid production decreases to an uneconomical level. In thismanner, heat provided to pyrolyze hydrocarbons within the formation mayalso be used to generate synthesis gas. For example, if a portion of theformation is at a temperature from approximately 270° C. toapproximately 375° C. (or 400° C. in some embodiments) afterpyrolyzation, then less additional heat is generally required to heatsuch portion to a temperature sufficient to support synthesis gasgeneration.

[0072] Pyrolysis of at least some hydrocarbons may in some embodimentsconvert about 15% by weight or more of the carbon initially available.Synthesis gas generation may convert approximately up to an additional80% by weight or more of carbon initially available within the portion.In this manner, in situ production of synthesis gas from a coalformation may allow conversion of larger amounts of carbon initiallyavailable within the portion. The amount of conversion achieved may, insome embodiments, be limited by subsidence concerns.

[0073] Certain embodiments may include providing heat from one or moreheat sources to heat the formation to a temperature sufficient to allowsynthesis gas generation (e.g., in a range of approximately 400° C. toapproximately 1200° C. or higher). At a lower end of the temperaturerange, generated synthesis gas may have a high hydrogen (H₂) to carbonmonoxide (CO) ratio. At an upper end of the temperature range, generatedsynthesis gas may include mostly H₂ and CO in lower ratios (e.g.,approximately a 1:1 ratio).

[0074] Heat sources for synthesis gas production may include any of theheat sources as described in any of the embodiments set forth herein.Alternatively, heating may include transferring heat from a heattransfer fluid (e.g., steam or combustion products from a burner)flowing within a plurality of wellbores within the formation.

[0075] A synthesis gas generating fluid (e.g., liquid water, steam,carbon dioxide, air, oxygen, hydrocarbons, and mixtures thereof) may beprovided to the formation. For example, the synthesis gas generatingfluid mixture may include steam and oxygen. In an embodiment, asynthesis gas generating fluid may include aqueous fluid produced bypyrolysis of at least some hydrocarbons within one or more otherportions of the formation. Providing the synthesis gas generating fluidmay alternatively include raising a water table of the formation toallow water to flow into it. Synthesis gas generating fluid may also beprovided through at least one injection wellbore. The synthesis gasgenerating fluid will generally react with carbon in the formation toform H₂, water, methane, CO₂, and/or CO. A portion of the carbon dioxidemay react with carbon in the formation to generate carbon monoxide.Hydrocarbons such as ethane may be added to a synthesis gas generatingfluid. When introduced into the formation, the hydrocarbons may crack toform hydrogen and/or methane. The presence of methane in producedsynthesis gas may increase the heating value of the produced synthesisgas.

[0076] Synthesis gas generating reactions are typically endothermicreactions. In an embodiment, an oxidant may be added to a synthesis gasgenerating fluid. The oxidant may include, but is not limited to, air,oxygen enriched air, oxygen, hydrogen peroxide, other oxidizing fluids,or combinations thereof. The oxidant may react with carbon within theformation to exothermically generate heat. Reaction of an oxidant withcarbon in the formation may result in production of CO₂ and/or CO.Introduction of an oxidant to react with carbon in the formation mayeconomically allow raising the formation temperature high enough toresult in generation of significant quantities of H₂ and CO fromhydrocarbons within the formation.

[0077] Synthesis gas generation may be via a batch process or acontinuous process, as is further described herein.

[0078] Synthesis gas may be produced from one or more producer wellsthat include one or more heat sources. Such heat sources may operate topromote production of the synthesis gas with a desired composition.

[0079] Certain embodiments may include monitoring a composition of theproduced synthesis gas, and then controlling heating and/or controllinginput of the synthesis gas generating fluid to maintain the compositionof the produced synthesis gas within a desired range. For example, insome embodiments (e.g., such as when the synthesis gas will be used as afeedstock for a Fischer-Tropsch process) a desired composition of theproduced synthesis gas may have a ratio of hydrogen to carbon monoxideof about 1.8:1 to 2.2:1 (e.g., about 2:1 or about 2.1:1). In someembodiments (such as when the synthesis gas will be used as a feedstockto make methanol) such ratio may be about 3:1 (e.g., about 2.8:1 to3.2:1).

[0080] Certain embodiments may include blending a first synthesis gaswith a second synthesis gas to produce synthesis gas of a desiredcomposition. The first and the second synthesis gases may be producedfrom different portions of the formation.

[0081] Synthesis gases described herein may be converted to heaviercondensable hydrocarbons. For example, a Fischer-Tropsch hydrocarbonsynthesis process may be configured to convert synthesis gas to branchedand unbranched paraffins. Paraffins produced from the Fischer-Tropschprocess may be used to produce other products such as diesel, jet fuel,and naphtha products. The produced synthesis gas may also be used in acatalytic methanation process to produce methane. Alternatively, theproduced synthesis gas may be used for production of methanol, gasolineand diesel fuel, ammonia, and middle distillates. Produced synthesis gasmay be used to heat the formation as a combustion fuel. Hydrogen inproduced synthesis gas may be used to upgrade oil.

[0082] Synthesis gas may also be used for other purposes. Synthesis gasmay be combusted as fuel. Synthesis gas may also be used forsynthesizing a wide range of organic and/or inorganic compounds such ashydrocarbons and ammonia. Synthesis gas may be used to generateelectricity, by combusting it as a fuel, by reducing the pressure of thesynthesis gas in turbines, and/or using the temperature of the synthesisgas to make steam (and then run turbines). Synthesis gas may also beused in an energy generation unit such as a molten carbonate fuel cell,a solid oxide fuel cell, or other type of fuel cell.

[0083] Certain embodiments may include separating a fuel cell feedstream from fluids produced from pyrolysis of at least some of thehydrocarbons within a formation. The fuel cell feed stream may includeH₂, hydrocarbons, and/or carbon monoxide. In addition, certainembodiments may include directing the fuel cell feed stream to a fuelcell to produce electricity. The electricity generated from thesynthesis gas or the pyrolyzation fluids in the fuel cell may beconfigured to power electrical heaters, which may be configured to heatat least a portion of the formation. Certain embodiments may includeseparating carbon dioxide from a fluid exiting the fuel cell. Carbondioxide produced from a fuel cell or a formation may be used for avariety of purposes.

[0084] In an embodiment, a portion of a formation that has beenpyrolyzed and/or subjected to synthesis gas generation may be allowed tocool or may be cooled to form a cooled, spent portion within theformation. For example, a heated portion of a formation may be allowedto cool by transference of heat to adjacent portion of the formation.The transference of heat may occur naturally or may be forced by theintroduction of heat transfer fluids through the heated portion and intoa cooler portion of the formation. Alternatively, introducing water tothe first portion of the formation may cool the first portion. Waterintroduced into the first portion may be removed from the formation assteam. The removed steam or hot water may be injected into a hot portionof the formation to create synthesis gas.

[0085] Cooling the formation may provide certain benefits such asincreasing the strength of the rock in the formation (thereby mitigatingsubsidence), increasing absorptive capacity of the formation, etc.

[0086] In an embodiment, a cooled, spent portion of a coal formation maybe used to store and/or sequester other materials such as carbondioxide. Carbon dioxide may be injected under pressure into the cooled,spent portion of the formation. The injected carbon dioxide may adsorbonto hydrocarbons in the formation and/or reside in void spaces such aspores in the formation. The carbon dioxide may be generated duringpyrolysis, synthesis gas generation, and/or extraction of useful energy.

[0087] In an embodiment, produced formation fluids may be stored in acooled, spent portion of the formation. In some embodiments carbondioxide may be stored in relatively deep coal beds, and used to desorbcoal bed methane.

BRIEF DESCRIPTION OF THE DRAWINGS

[0088] Further advantages of the present invention may become apparentto those skilled in the art with the benefit of the following detaileddescription of the preferred embodiments and upon reference to theaccompanying drawings in which:

[0089]FIG. 1 depicts an illustration of stages of heating a coalformation;

[0090]FIG. 2 depicts a diagram of properties of a coal formation;

[0091]FIG. 3 depicts an embodiment of a heat source pattern;

[0092]FIGS. 3a-3 c depict embodiments of heat sources;

[0093]FIG. 4 depicts an embodiment of heater wells located in a coalformation;

[0094]FIG. 5 depicts an embodiment of a pattern of heater wells in acoal formation;

[0095]FIG. 6 depicts an embodiment of a heated portion of a coalformation;

[0096]FIG. 7 depicts an embodiment of superposition of heat in a coalformation;

[0097]FIG. 8 and FIG. 9 depict embodiments of a pattern of heat sourcesand production wells in a coal formation;

[0098]FIG. 10 depicts an embodiment of a natural distributed combustorheat source;

[0099]FIG. 11 depicts a portion of an overburden of a formation with aheat source;

[0100]FIG. 12 and FIG. 13 depict embodiments of a natural distributedcombustor heater;

[0101]FIG. 14 and FIG. 15 depict embodiments of a system for heating aformation;

[0102] FIGS. 16-21 depict several embodiments of an insulated conductorheat source;

[0103]FIG. 22 and FIGS. 23a-23 b depict several embodiments of acentralizer;

[0104]FIG. 24 depicts an embodiment of a conductor-in-conduit heatsource in a formation;

[0105]FIG. 25 depicts an embodiment of a heat source in a formation;

[0106]FIG. 26 depicts an embodiment of a surface combustor heat source;

[0107]FIG. 27 depicts an embodiment of a conduit for a heat source;

[0108]FIG. 28 depicts an embodiment of a flameless combustor heatsource;

[0109]FIG. 29 depicts an embodiment of using pyrolysis water to generatesynthesis gas in a formation;

[0110]FIG. 30 depicts an embodiment of synthesis gas production in aformation;

[0111]FIG. 31 depicts an embodiment of continuous synthesis gasproduction in a formation;

[0112]FIG. 32 depicts an embodiment of batch synthesis gas production ina formation;

[0113]FIG. 33 depicts an embodiment of producing energy with synthesisgas produced from a coal formation;

[0114]FIG. 34 depicts an embodiment of producing energy withpyrolyzation fluid produced from a coal formation;

[0115]FIG. 35 depicts an embodiment of synthesis gas production from aformation;

[0116]FIG. 36 depicts an embodiment of sequestration of carbon dioxideproduced during pyrolysis in a coal formation;

[0117]FIG. 37 depicts an embodiment of producing energy with synthesisgas produced from a coal formation;

[0118]FIG. 38 depicts an embodiment of a Fischer-Tropsch process usingsynthesis gas produced from a coal formation;

[0119]FIG. 39 depicts an embodiment of a Shell Middle Distillatesprocess using synthesis gas produced from a coal formation;

[0120]FIG. 40 depicts an embodiment of a catalytic methanation processusing synthesis gas produced from a coal formation;

[0121]FIG. 41 depicts an embodiment of production of ammonia and ureausing synthesis gas produced from a coal formation;

[0122]FIG. 42 depicts an embodiment of production of ammonia usingsynthesis gas produced from a coal formation;

[0123]FIG. 43 depicts an embodiment of preparation of a feed stream foran ammonia process;

[0124] FIGS. 44-57 depict several embodiments of a heat source andproduction well pattern;

[0125]FIG. 58 depicts an embodiment of surface facilities for treating aformation fluid;

[0126]FIG. 59 depicts an embodiment of a catalytic flameless distributedcombustor;

[0127]FIG. 60 depicts an embodiment of surface facilities for treating aformation fluid;

[0128]FIG. 61 depicts an embodiment of a square pattern of heat sourcesand production wells;

[0129]FIG. 62 depicts an embodiment of a heat source and production wellpattern;

[0130]FIG. 63 depicts an embodiment of a triangular pattern of heatsources;

[0131]FIG. 64 depicts an embodiment of a square pattern of heat sources;

[0132]FIG. 65 depicts an embodiment of a hexagonal pattern of heatsources;

[0133]FIG. 66 depicts an embodiment of a 12 to 1 pattern of heatsources;

[0134]FIG. 67 depicts extension of a reaction zone in a heated formationover time;

[0135]FIG. 68 and FIG. 69 depict the ratio of conductive heat transferto radiative heat transfer in a formation;

[0136] FIGS. 70-73 depict temperatures of a conductor, a conduit, and anopening in a formation versus a temperature at the face of a formation;

[0137]FIG. 74 depicts a retort and collection system;

[0138]FIG. 75 depicts an embodiment of an apparatus for a drumexperiment;

[0139]FIG. 76 depicts a plot of ethene to ethane ratio versus hydrogenconcentration;

[0140]FIG. 77 depicts weight percent of paraffins versus vitrinitereflectance;

[0141]FIG. 78 depicts weight percent of cycloalkanes in produced oilversus vitrinite reflectance;

[0142]FIG. 79 depicts weight percentages of paraffins and cycloalkanesin produced oil versus vitrinite reflectance;

[0143]FIG. 80 depicts phenol weight percent in produced oil versusvitrinite reflectance;

[0144]FIG. 81 depicts aromatic weight percent in produced oil versusvitrinite reflectance;

[0145]FIG. 82 depicts ratio of paraffins and aliphatics to aromaticsversus vitrinite reflectance;

[0146]FIG. 83 depicts yields of paraffins versus vitrinite reflectance;

[0147]FIG. 84 depicts yields of cycloalkanes versus vitrinitereflectance;

[0148]FIG. 85 depicts yields of cycloalkanes and paraffins versusvitrinite reflectance;

[0149]FIG. 86 depicts yields of phenol versus vitrinite reflectance;

[0150]FIG. 87 depicts API gravity as a function of vitrinitereflectance;

[0151]FIG. 88 depicts yield of oil from a coal formation as a functionof vitrinite reflectance;

[0152]FIG. 89 depicts CO₂ yield from coal having various vitrinitereflectances;

[0153]FIG. 90 depicts CO₂ yield versus atomic O/C ratio for a coalformation;

[0154]FIG. 91 depicts a schematic of a coal cube experiment;

[0155]FIG. 92 depicts in situ temperature profiles for electricalresistance heaters, and natural distributed combustion heaters;

[0156]FIG. 93 depicts equilibrium gas phase compositions produced fromexperiments on a coal cube;

[0157]FIG. 94 depicts cumulative production of gas as a function oftemperature produced by heating a coal cube;

[0158]FIG. 95 depicts cumulative condensable hydrocarbons and water as afunction of temperature produced by heating a coal cube;

[0159]FIG. 96 depicts the compositions of condensable hydrocarbonsproduced when various ranks of coal were treated;

[0160]FIG. 97 depicts thermal conductivity of coal versus temperature;

[0161]FIG. 98 depicts a cross-sectional view of an in situ experimentalfield test;

[0162]FIG. 99 depicts locations of heat sources and wells in anexperimental field test;

[0163]FIG. 100 and FIG. 101 depict temperature versus time in anexperimental field test;

[0164]FIG. 102 depicts volume of oil produced from an experimental fieldtest as a function of time;

[0165]FIG. 103 depicts carbon number distribution of fluids producedfrom an experimental field test;

[0166]FIG. 104 depicts weight percent of a hydrocarbon produced from twolaboratory experiments on coal from the 1 field test site versus carbonnumber distribution;

[0167]FIG. 105 depicts fractions from separation of coal oils treated byFischer assay and treated by slow heating in a coal cube experiment;

[0168]FIG. 106 depicts percentage ethene to ethane produced from a coalformation as a function of heating rate in an experimental field test;

[0169]FIG. 107 depicts product quality of fluids produced from a coalformation as a function of heating rate in an experimental field test;

[0170]FIG. 108 depicts weight percentages of various fluids producedfrom a coal formation for various heating rates in an experimental fieldtest;

[0171]FIG. 109 depicts CO₂ produced at three different locations versustime in an experimental field test;

[0172]FIG. 110 depicts volatiles produced from a coal formation in anexperimental field test versus cumulative energy content;

[0173]FIG. 111 depicts volume of gas produced from a coal formation inan experimental field test as a function of time;

[0174]FIG. 112 depicts volume of oil produced from a coal formation inan experimental field test as a function of energy input;

[0175]FIG. 113 depicts synthesis gas production from the coal formationin an experimental field test versus the total water inflow;

[0176]FIG. 114 depicts additional synthesis gas production from the coalformation in an experimental field test due to injected steam;

[0177]FIG. 115 depicts the effect of methane injection into a heatedformation;

[0178]FIG. 116 depicts the effect of ethane injection into a heatedformation;

[0179]FIG. 117 depicts the effect of propane injection into a heatedformation;

[0180]FIG. 118 depicts the effect of butane injection into a heatedformation;

[0181]FIG. 119 depicts composition of gas produced from a formationversus time;

[0182]FIG. 120 depicts synthesis gas conversion versus time;

[0183]FIG. 121 depicts calculated equilibrium gas dry mole fractions fora reaction of coal with water;

[0184]FIG. 122 depicts calculated equilibrium gas wet mole fractions fora reaction of coal with water;

[0185]FIG. 123 depicts an example of pyrolysis and synthesis gasproduction stages in a coal formation;

[0186]FIG. 124 depicts an example of low temperature in situ synthesisgas production;

[0187]FIG. 125 depicts an example of high temperature in situ synthesisgas production;

[0188]FIG. 126 depicts an example of in situ synthesis gas production ina coal formation;

[0189]FIG. 127 depicts a plot of cumulative adsorbed methane and carbondioxide versus pressure in a coal formation;

[0190]FIG. 128 depicts an embodiment of in situ synthesis gas productionintegrated with a Fischer-Tropsch process;

[0191]FIG. 129 depicts a comparison between numerical simulation dataand experimental field test data of synthesis gas composition producedas a function of time;

[0192]FIG. 130 depicts pressure at wellheads as a function of time froma numerical simulation;

[0193]FIG. 131 depicts production rate of carbon dioxide and methane asa function of time from a numerical simulation;

[0194]FIG. 132 depicts cumulative methane produced and net carbondioxide injected as a function of time from a numerical simulation;

[0195]FIG. 133 depicts pressure at wellheads as a function of time froma numerical simulation;

[0196]FIG. 134 depicts production rate of carbon dioxide as a functionof time from a numerical simulation; and

[0197]FIG. 135 depicts cumulative net carbon dioxide injected as afunction of time from a numerical simulation.

[0198] While the invention is susceptible to various modifications andalternative forms, specific embodiments thereof are shown by way ofexample in the drawings and may herein be described in detail. Thedrawings may not be to scale. It should be understood, however, that thedrawings and detailed description thereto are not intended to limit theinvention to the particular form disclosed, but on the contrary, theintention is to cover all modifications, equivalents and alternativesfalling within the spirit and scope of the present invention as definedby the appended claims.

DETAILED DESCRIPTION OF THE INVENTION

[0199] The following description generally relates to systems andmethods for treating a coal formation, which may include, but is notlimited to, humic and/or sapropelic coal. Such formations may be treatedto yield relatively high quality hydrocarbon products, hydrogen, andother products.

[0200] As used herein, the word “coal” is generally defined to includenaturally formed sedimentary rock or other rock that contains at leastabout 70% by volume of organic matter.

[0201] As used herein, “a method of treating a coal formation” may beused interchangeably with “an in situ conversion process for coal.”

[0202] “Hydrocarbons” are generally defined as organic material thatcontains carbon and hydrogen in their molecular structures. Hydrocarbonsmay also include other elements, such as, but not limited to, halogens,metallic elements, nitrogen, oxygen, and/or sulfur.

[0203] “Kerogen” is generally defined as a solid, insoluble hydrocarbonthat has been converted by natural degradation (e.g., by diagenesis) andthat principally contains carbon, hydrogen, nitrogen, oxygen, andsulfur. Coal is a typical example of a material that contains kerogens.“Oil” is generally defined as a fluid containing a complex mixture ofcondensable hydrocarbons.

[0204] The terms “formation fluids” and “produced fluids” generallyrefer to fluids removed from a coal formation and may includepyrolyzation fluid, synthesis gas, and water (steam). Formation fluidsmay include hydrocarbon fluids as well as non-hydrocarbon fluids. Asused herein, “hydrocarbon fluids” generally refer to compounds includingprimarily hydrogen and carbon. Hydrocarbon fluids may include otherelements in addition to hydrogen and carbon such as, but not limited to,nitrogen, oxygen, and sulfur. Non-hydrocarbon fluids may include, butare not limited to, hydrogen (“H₂”), nitrogen (“N₂”), carbon monoxide,carbon dioxide, hydrogen sulfide, water, and ammonia.

[0205] A “carbon number” generally refers to a number of carbon atomswithin a molecule. As described herein, carbon number distributions aredetermined by true boiling point distribution and gas liquidchromatography.

[0206] A “heat source” is generally defined as any system configured toprovide heat to at least a portion of a formation. For example, a heatsource may include electrical heaters such as an insulated conductor, anelongated member, and a conductor disposed within a conduit, asdescribed in embodiments herein. A heat source may also include heatsources that generate heat by burning a fuel external to or within aformation such as surface burners, flameless distributed combustors, andnatural distributed combustors, as described in embodiments herein. Inaddition, it is envisioned that in some embodiments heat provided to orgenerated in one or more heat sources may by supplied by other sourcesof energy. The other sources of energy may directly heat a formation, orthe energy may be applied to a transfer media that directly orindirectly heats the formation. It is to be understood that one or moreheat sources that are applying heat to a formation may use differentsources of energy. Thus, for example, for a given formation some heatsources may supply heat from electric resistance heaters, some heatsources may provide heat from combustion, and some heat sources mayprovide heat from one or more other energy sources (e.g., chemicalreactions, solar energy, wind energy, or other sources of renewableenergy). A chemical reaction may include an exothermic reaction such as,but not limited to, an oxidation reaction that may take place in atleast a portion of a formation. A heat source may also include a heaterthat may be configured to provide heat to a zone proximate to and/orsurrounding a heating location such as a heater well. Heaters may be,but are not limited to, electric heaters, burners, and naturaldistributed combustors.

[0207] A “heater” is generally defined as any system configured togenerate heat in a well or a near wellbore region. A “unit of heatsources” refers to a minimal number of heat sources that form a templatethat is repeated to create a pattern of heat sources within a formation.For example, a heater may generate heat by burning a fuel external to orwithin a formation such as surface burners, flameless distributedcombustors, and natural distributed combustors, as described inembodiments herein.

[0208] The term “wellbore” generally refers to a hole in a formationmade by drilling. A wellbore may have a substantially circularcross-section, or a cross-section in other shapes as well (e.g.,circles, ovals, squares, rectangles, triangles, slits, or other regularor irregular shapes). As used herein, the terms “well” and “opening,”when referring to an opening in the formation, may also be usedinterchangeably with the term “wellbore.”

[0209] As used herein, the phrase “natural distributed combustor”generally refers to a heater that uses an oxidant to oxidize at least aportion of the carbon in the formation to generate heat, and wherein theoxidation takes place in a vicinity proximate to a wellbore. Most of thecombustion products produced in the natural distributed combustor areremoved through the wellbore.

[0210] The term “orifices,” as used herein, generally describes openingshaving a wide variety of sizes and cross-sectional shapes including, butnot limited to, circles, ovals, squares, rectangles, triangles, slits,or other regular or irregular shapes.

[0211] As used herein, a “reaction zone” generally refers to a volume ofa coal formation that is subjected to a chemical reaction such as anoxidation reaction.

[0212] As used herein, the term “insulated conductor” generally refersto any elongated material that may conduct electricity and that iscovered, in whole or in part, by an electrically insulating material.The term “self-controls” generally refers to controlling an output of aheater without external control of any type.

[0213] “Pyrolysis” is generally defined as the breaking of chemicalbonds due to the application of heat. For example, pyrolysis may includetransforming a compound into one or more other substances by heat alone.In the context of this patent, heat for pyrolysis may originate in anoxidation reaction and then such heat may be transferred to a section ofthe formation to cause pyrolysis.

[0214] As used herein, a “pyrolyzation fluid” or “pyrolysis products”generally refers to a fluid produced substantially during pyrolysis ofhydrocarbons. As used herein, a “pyrolysis zone” generally refers to avolume of coal formation that is reacted or reacting to form apyrolyzation fluid.

[0215] “Cracking” generally refers to a process involving decompositionand molecular recombination of organic compounds wherein a number ofmolecules becomes larger. In cracking, a series of reactions take placeaccompanied by a transfer of hydrogen atoms between molecules. Crackingfundamentally changes the chemical structure of the molecules. Forexample, naphtha may undergo a thermal cracking reaction to form etheneand H₂.

[0216] The term “superposition of heat” is generally defined asproviding heat from at least two heat sources to a selected section ofthe portion of the formation such that the temperature of the formationat least at one location between the two wells is influenced by at leasttwo heat sources.

[0217] The term “fingering” generally refers to injected fluidsbypassing portions of a formation because of variations in transportcharacteristics (e.g., permeability).

[0218] “Thermal conductivity” is generally defined as the property of amaterial that describes the rate at which heat flows, in steady state,between two surfaces of the material for a given temperature differencebetween the two surfaces.

[0219] “Fluid pressure” is generally defined as a pressure generated bya fluid within a formation. “Lithostatic pressure” is sometimes referredto as lithostatic stress and is generally defined as a pressure within aformation equal to a weight per unit area of an overlying rock mass.“Hydrostatic pressure” is generally defined as a pressure within aformation exerted by a column of water.

[0220] “Condensable hydrocarbons” means the hydrocarbons that condenseat 25° C. at one atmosphere absolute pressure. Condensable hydrocarbonsmay include a mixture of hydrocarbons having carbon numbers greater than4. “Non-condensable hydrocarbons” means the hydrocarbons that do notcondense at 25° C. and one atmosphere absolute pressure. Non-condensablehydrocarbons may include hydrocarbons having carbon numbers less than 5.

[0221] “Olefins” are generally defined as unsaturated hydrocarbonshaving one or more non-aromatic carbon-to-carbon double bonds.

[0222] “Urea” is generally described by a molecular formula ofNH₂—CO—NH₂. Urea can be used as a fertilizer.

[0223] “Synthesis gas” is generally defined as a mixture includinghydrogen and carbon monoxide used for synthesizing a wide range ofcompounds. Additional components of synthesis gas may include water,carbon dioxide, nitrogen, methane and other gases. Synthesis gas may begenerated by a variety of processes and feedstocks.

[0224] “Reforming” is generally defined as the reaction of hydrocarbons(such as methane or naphtha) with steam to produce CO and H₂ as majorproducts. Generally it is conducted in the presence of a catalystalthough it can be performed thermally without the presence of acatalyst.

[0225] “Sequestration” generally refers to storing a gas that is aby-product of a process rather than venting the gas to the atmosphere.

[0226] The term “dipping” is generally defined as sloping downward orinclining from a plane parallel to the earth's surface, assuming theplane is flat (i.e., a “horizontal” plane). A “dip” is generally definedas an angle that a stratum or similar feature may make with a horizontalplane. A “steeply dipping” coal formation generally refers to a coalformation lying at an angle of at least 20° from a horizontal plane. Asused herein, “down dip” generally refers to downward along a directionparallel to a dip in a formation. As used herein, “up dip” generallyrefers to upward along a direction parallel to a dip of a formation.“Strike” refers to the course or bearing of hydrocarbon material that isnormal to the direction of the dip.

[0227] The term “subsidence” is generally defined as downward movementof a portion of a formation relative to an initial elevation of thesurface.

[0228] “Thickness” of a layer refers to the thickness of a cross-sectionof a layer, wherein the cross-section is normal to a face of the layer.

[0229] “Coring” is generally defined as a process that generallyincludes drilling a hole into a formation and removing a substantiallysolid mass of the formation from the hole.

[0230] A “surface unit” is generally defined as an ex situ treatmentunit.

[0231] “Middle distillates” generally refers to hydrocarbon mixtureswith a boiling point range that may correspond substantially with thatof kerosene and gas oil fractions obtained in a conventional atmosphericdistillation of crude oil material. The middle distillate boiling pointrange may include temperatures between about 150° C. and about 360° C.,with a fraction boiling point between about 200° C. and about 360° C.Middle distillates may be referred to as gas oil.

[0232] A “boiling point cut” is generally defined as a hydrocarbonliquid fraction that may be separated from hydrocarbon liquids when thehydrocarbon liquids are heated to a boiling point range of the fraction.

[0233] The term “selected mobilized section” refers to a section of arelatively permeable formation that is at an average temperature withina mobilization temperature range. The term “selected pyrolyzationsection” refers to a section of a relatively permeable formation that isat an average temperature within a pyrolyzation temperature range.

[0234] “Enriched air” generally refers to air having a larger molefraction of oxygen than air in the atmosphere. Enrichment of air istypically done to increase its combustion-supporting ability.

[0235] The phrase “off peak” times generally refers to times ofoperation where utility energy is less commonly used and, therefore,less expensive.

[0236] “Thermal fracture” refers to fractures created in a formationcaused by expansion or contraction of a formation and/or fluids withinthe formation, which is in turn caused by increasing/decreasing thetemperature of the formation and/or fluids within the formation, and/orby increasing/decreasing a pressure of fluids within the formation dueto heating.

[0237] Hydrocarbons in coal formations may be treated in various ways toproduce many different products. In certain embodiments such formationsmay be treated in stages. FIG. 1 illustrates several stages of heating acoal formation. FIG. 1 also depicts an example of yield (barrels of oilequivalent per ton) (y axis) of formation fluids from a coal formationversus temperature (° C.) (x axis) of the formation.

[0238] Desorption of methane and vaporization of water occurs duringstage 1 heating in FIG. 1. For example, when a coal formation isinitially heated, hydrocarbons in the formation may desorb adsorbedmethane. The desorbed methane may be produced from the formation. If thecoal formation is heated further, water within the coal formation may bevaporized. In addition, the vaporized water may be produced from theformation. Heating of the formation through stage 1 is in many instancespreferably performed as quickly as possible.

[0239] After stage 1 heating, the formation may be heated further suchthat a temperature within the formation reaches (at least) an initialpyrolyzation temperature (e.g., the temperature at the lower end of thetemperature range shown as stage 2). A pyrolysis temperature range mayvary depending on types of hydrocarbons within the formation. Forexample, a pyrolysis temperature range may include temperatures betweenabout 250° C. and about 900° C. In an alternative embodiment, apyrolysis temperature range may include temperatures between about 270°C. to about 400° C. Hydrocarbons within the formation may be pyrolyzedthroughout stage 2.

[0240] Formation fluids including pyrolyzation fluids may be producedfrom the formation. The pyrolyzation fluids may include, but are notlimited to, hydrocarbons, hydrogen, carbon dioxide, carbon monoxide,hydrogen sulfide, ammonia, nitrogen, water and mixtures thereof. As thetemperature of the formation increases, the condensable hydrocarbons ofproduced formation fluid tends to decrease, and the formation will inmany instances tend to produce mostly methane and hydrogen. If a coalformation is heated throughout an entire pyrolysis range, the formationmay produce only small amounts of hydrogen towards an upper limit of thepyrolysis range. After all of the available hydrogen is depleted, aminimal amount of fluid production from the formation will typicallyoccur.

[0241] After pyrolysis of hydrocarbons, a large amount of carbon andsome hydrogen may still be present in the formation. A significantportion of remaining carbon in the formation can be produced from theformation in the form of synthesis gas. Synthesis gas generation maytake place during stage 3 heating as shown in FIG. 1. Stage 3 mayinclude heating a coal formation to a temperature sufficient to allowsynthesis gas generation. For example, synthesis gas may be producedwithin a temperature range from about 400° C. to about 1200° C. Thetemperature of the formation when the synthesis gas generating fluid isintroduced to the formation will in many instances determine thecomposition of synthesis gas produced within the formation. If asynthesis gas generating fluid is introduced into a formation at atemperature sufficient to allow synthesis gas generation, then synthesisgas may be generated within the formation. The generated synthesis gasmay be removed from the formation. A large volume of synthesis gas maybe produced during generation of synthesis gas generation.

[0242] Depending on the amounts of fluid produced, total energy contentof fluids produced from a coal formation may in some instances stayrelatively constant throughout pyrolysis and synthesis gas generation.For example, during pyrolysis, at relatively low formation temperatures,a significant portion of the produced fluid may be condensablehydrocarbons that have a high energy content. At higher pyrolysistemperatures, however, less of the formation fluid may includecondensable hydrocarbons, and more non-condensable formation fluids maybe produced. In this manner, energy content per unit volume of theproduced fluid may decline slightly during generation of predominantlynon-condensable formation fluids. During synthesis gas generation,energy content per unit volume of produced synthesis gas declinessignificantly compared to energy content of pyrolyzation fluid. Thevolume of the produced synthesis gas, however, will in many instanceincrease substantially, thereby compensating for the decreased energycontent.

[0243] As explained below, the van Krevelen diagram shown in FIG. 2depicts a plot of atomic hydrogen to carbon ratio (y axis) versus atomicoxygen to carbon ratio (x axis) for various types of kerogen. Thisdiagram shows the maturation sequence for various types of kerogen thattypically occurs over geologic time due to temperature, pressure, andbiochemical degradation. The maturation may be accelerated by heating insitu at a controlled rate and/or a controlled pressure.

[0244] A van Krevelen diagram may be useful for selecting a resource forpracticing various embodiments described herein (see discussion below).Treating a formation containing kerogen in region 5 will in manyinstances produce, e.g., carbon dioxide, non-condensable hydrocarbons,hydrogen, and water, along with a relatively small amount of condensablehydrocarbons. Treating a formation containing kerogen in region 7 willin many instances produce, e.g., carbon condensable and non-condensablehydrocarbons, carbon dioxide, hydrogen, and water. Treating a formationcontaining kerogen in region 9 will in many instances produce, e.g.,methane and hydrogen. A formation containing kerogen in region 7, forexample, may in many instances be selected for treatment because doingso will tend to produce larger quantities of valuable hydrocarbons, andlower quantities of undesirable products such as carbon dioxide andwater, since the region 7 kerogen has already undergone dehydrationand/or decarboxylation over geological time. In addition, region 7kerogen can also be further treated to make other useful products (e.g.,methane, hydrogen, and/or synthesis gas) as such kerogen transforms toregion 9 kerogen.

[0245] If a formation containing kerogen in region 5 or 7 was selectedfor treatment, then treatment pursuant to certain embodiments describedherein would cause such kerogen to transform during treatment (seearrows in FIG. 2) to a region having a higher number (e.g., region 5kerogen could transform to region 7 kerogen and possibly then to region9 kerogen, or region 7 kerogen could transform to region 9 kerogen).Thus, certain embodiments described herein cause expedited maturation ofkerogen, thereby allowing production of valuable products.

[0246] If region 5 kerogen, for example, is treated, then substantialcarbon dioxide may be produced due to decarboxylation of hydrocarbons inthe formation. In addition, treating region 5 kerogen may also producesome hydrocarbons (e.g., primarily methane). Treating region 5 kerogenmay also produce substantial amounts of water due to dehydration ofkerogen in the formation. Production of such compounds from a formationmay leave residual hydrocarbons relatively enriched in carbon. Oxygencontent of the hydrocarbons will in many instances decrease faster thana hydrogen content of the hydrocarbons during production of suchcompounds. Therefore, as shown in FIG. 2, production of such compoundsmay result in a larger decrease in the atomic oxygen to carbon ratiothan a decrease in the atomic hydrogen to carbon ratio (see region 5arrows in FIG. 2 which depict more horizontal than vertical movement).

[0247] If region 7 kerogen is treated, then typically at least some ofthe hydrocarbons in the formation are pyrolyzed to produce condensableand non-condensable hydrocarbons. For example, treating region 7 kerogenmay result in production of oil from hydrocarbons, as well as somecarbon dioxide and water (albeit generally less carbon dioxide and waterthan is produced when the region 5 kerogen is treated). Therefore, theatomic hydrogen to carbon ratio of the kerogen will in many instancesdecrease rapidly as the kerogen in region 7 is treated. The atomicoxygen to carbon ratio of the region 7 kerogen, however, will in manyinstances decrease much slower than the atomic hydrogen to carbon ratioof the region 7 kerogen.

[0248] Kerogen in region 9 may be treated to generate methane andhydrogen. For example, if such kerogen was previously treated (e.g., itwas previously region 7 kerogen), then after pyrolysis longerhydrocarbon chains of the hydrocarbons may have already cracked andproduced from the formation. Carbon and hydrogen, however, may still bepresent in the formation.

[0249] If kerogen in region 9 were heated to a synthesis gas generatingtemperature and a synthesis gas generating fluid (e.g., steam) wereadded to the region 9 kerogen, then at least a portion of remaininghydrocarbons in the formation may be produced from the formation in theform of synthesis gas. For region 9 kerogen, the atomic hydrogen tocarbon ratio and the atomic oxygen to carbon ratio in the hydrocarbonsmay significantly decrease as the temperature rises. In this manner,hydrocarbons in the formation may be transformed into relatively purecarbon in region 9. Heating region 9 kerogen to still highertemperatures will tend to transform such kerogen into graphite 11.

[0250] A coal formation may have a number of properties that will dependon, for example, a composition of at least some of the hydrocarbonswithin the formation. Such properties tend to affect the composition andamount of products that are produced from a coal formation. Therefore,properties of a coal formation can be used to determine if and/or how acoal formation could optimally be treated.

[0251] Coal formations typically contain kerogen. Kerogen is composed oforganic matter that has been transformed due to a maturation process.The maturation process may include two stages: a biochemical stage and ageochemical stage. The biochemical stage typically involves degradationof organic material by both aerobic and anaerobic organisms. Thegeochemical stage typically involves conversion of organic matter due totemperature changes and significant pressures. During maturation, oiland gas may be produced as the organic matter of the kerogen istransformed.

[0252] The van Krevelen diagram shown in FIG. 2 classifies variousnatural deposits of kerogen. For example, kerogen may be classified intofour distinct groups: type I, type II, type III, and type IV, which areillustrated by the four branches of the van Krevelen diagram. Thisdrawing shows the maturation sequence for kerogen, which typicallyoccurs over geological time due to temperature and pressure. The typesdepend upon precursor materials of the kerogen. The precursor materialstransform over time into macerals, which are microscopic structures thathave different structures and properties based on the precursormaterials from which they are derived. Oil shale may be described as akerogen type I or type II and may primarily contain macerals from theliptinite group. Type II kerogen may develop from organic matter thatwas deposited in marine environments.

[0253] Type III kerogen may generally include vitrinite macerals.Vitrinite is derived from cell walls and/or woody tissues (e.g., stems,branches, leaves and roots of plants). Type III kerogen may be presentin most humic coals. Type III kerogen may develop from organic matterthat was deposited in swamps. Type IV kerogen includes the inertinitemaceral group. This group is composed of plant material such as leaves,bark and stems that have undergone oxidation during the early peatstages of burial diagenesis. It is chemically similar to vitrinite buthas a high carbon and low hydrogen content. Thus, it is consideredinert.

[0254] The dashed lines in FIG. 2 correspond to vitrinite reflectance.The vitrinite reflectance is a measure of maturation. As kerogenundergoes maturation, the composition of the kerogen usually changes.For example, as kerogen undergoes maturation, volatile matter of kerogentends to decrease. Rank classifications of kerogen indicate the level towhich kerogen has matured. For example, as kerogen undergoes maturation,the rank of kerogen increases. Therefore, as rank increases, thevolatile matter of kerogen tends to decrease. In addition, the moisturecontent of kerogen generally decreases as the rank increases. At higherranks, however, the moisture content may become relatively constant. Forexample, higher rank kerogens that have undergone significantmaturation, such as semi-anthracite or anthracite coal, tend to have ahigher carbon content and a lower volatile matter content than lowerrank kerogens such as lignite. For example, rank stages of coalformations include the following classifications, which are listed inorder of increasing rank and maturity for type III kerogen: wood, peat,lignite, sub-bituminous coal, high volatile bituminous coal, mediumvolatile bituminous coal, low volatile bituminous coal, semi-anthracite,and anthracite. In addition, as rank increases, kerogen tends to exhibitan increase in aromatic nature.

[0255] Coal formations may be selected for in situ treatment based onproperties of at least a portion of the formation. For example, aformation may be selected based on richness, thickness, and depth (i.e.,thickness of overburden) of the formation. In addition, a formation maybe selected that will have relatively high quality fluids produced fromthe formation. In certain embodiments the quality of the fluids to beproduced may be assessed in advance of treatment, thereby generatingsignificant cost savings since only more optimal formations will beselected for treatment. Properties that may be used to assesshydrocarbons in a coal formation include, but are not limited to, anamount of hydrocarbon liquids that tend to be produced from thehydrocarbons, a likely API gravity of the produced hydrocarbon liquids,an amount of hydrocarbon gas that tend to be produced from thehydrocarbons, and/or an amount of carbon dioxide and water that tend tobe produced from the hydrocarbons.

[0256] Another property that may be used to assess the quality of fluidsproduced from certain coal formations is vitrinite reflectance. Coalformations that include kerogen can typically be assessed/selected fortreatment based on a vitrinite reflectance of the kerogen. Vitrinitereflectance is often related to a hydrogen to carbon atomic ratio of akerogen and an oxygen to carbon atomic ratio of the kerogen, as shown bythe dashed lines in FIG. 2. For example, a van Krevelen diagram may beuseful in selecting a resource for an in situ conversion process.

[0257] Vitrinite reflectance of a kerogen in a coal formation tends toindicate which fluids may be produced from a formation upon heating. Forexample, a vitrinite reflectance of approximately 0.5% to approximately1.5% tends to indicate a kerogen that, upon heating, will produce fluidsas described in region 7 above. Therefore, if a coal formation havingsuch kerogen is heated, a significant amount (e.g., majority) of thefluid produced by such heating will often include oil and other suchhydrocarbon fluids. In addition, a vitrinite reflectance ofapproximately 1.5% to 3.0% may indicate a kerogen in region 9 asdescribed above. If a coal formation having such kerogen is heated, asignificant amount (e.g., majority) of the fluid produced by suchheating may include methane and hydrogen (and synthesis gas, if, forexample, the temperature is sufficiently high and steam is injected). Inan embodiment, at least a portion of a coal formation selected fortreatment in situ has a vitrinite reflectance in a range between about0.2% and about 3.0%. Alternatively, at least a portion of a coalformation selected for treatment has a vitrinite reflectance from about0.5% to about 2.0%, and, in some circumstances, the vitrinitereflectance may range from about 0.5% to 1.0%. Such ranges of vitrinitereflectance tend to indicate that relatively higher quality formationfluids will be produced from the formation.

[0258] In an embodiment, a coal formation may be selected for treatmentbased on a hydrogen content within the hydrocarbons in the formation.For example, a method of treating a coal formation may include selectinga portion of the coal formation for treatment having hydrocarbons with ahydrogen content greater than about 3 weight %, 3.5 weight %, or 4weight % when measured on a dry, ash-free basis. In addition, a selectedsection of a coal formation may include hydrocarbons with an atomichydrogen to carbon ratio that falls within a range from about 0.5 toabout 2, and in many instances from about 0.70 to about 1.65.

[0259] Hydrogen content of a coal formation may significantly affect acomposition of hydrocarbon fluids produced from a formation. Forexample, pyrolysis of at least some of the hydrocarbons within theheated portion may generate hydrocarbon fluids that may include a doublebond or a radical. Hydrogen within the formation may reduce the doublebond to a single bond. In this manner, reaction of generated hydrocarbonfluids with each other and/or with additional components in theformation may be substantially inhibited. For example, reduction of adouble bond of the generated hydrocarbon fluids to a single bond mayreduce polymerization of the generated hydrocarbons. Such polymerizationtends to reduce the amount of fluids produced.

[0260] In addition, hydrogen within the formation may also neutralizeradicals in the generated hydrocarbon fluids. In this manner, hydrogenpresent in the formation may substantially inhibit reaction ofhydrocarbon fragments by transforming the hydrocarbon fragments intorelatively short chain hydrocarbon fluids. The hydrocarbon fluids mayenter a vapor phase and may be produced from the formation. The increasein the hydrocarbon fluids in the vapor phase may significantly reduce apotential for producing less desirable products within the selectedsection of the formation.

[0261] It is believed that if too little hydrogen is present in theformation, then the amount and quality of the produced fluids will benegatively affected. If too little hydrogen is naturally present, thenin some embodiments hydrogen or other reducing fluids may be added tothe formation.

[0262] When heating a portion of a coal formation, oxygen within theportion may form carbon dioxide. It may be desirable to reduce theproduction of carbon dioxide and other oxides. In an embodiment,production of carbon dioxide may be reduced by selecting and treating aportion of a coal formation having a vitrinite reflectance of greaterthan about 0.5%. In addition, an amount of carbon dioxide produced froma formation may vary depending on, for example, an oxygen content of atreated portion of the coal formation. Certain embodiments may thusinclude selecting and treating a portion of the formation having akerogen with an atomic oxygen weight percentage of less than about 20%,15%, and/or 10%. In addition, certain embodiments may include selectingand processing a formation containing kerogen with an atomic oxygen tocarbon ratio of less than about 0.15. Alternatively, at least some ofthe hydrocarbons in a portion of a formation selected for treatment mayhave an atomic oxygen to carbon ratio of about 0.03 to about 0.12. Inthis manner, production of carbon dioxide and other oxides from an insitu conversion process for coal may be reduced.

[0263] Heating a coal formation may include providing a large amount ofenergy to heat sources located within the formation. Coal formations maycontain water. Water present in the coal formation will tend to furtherincrease the amount of energy required to heat a coal formation. In thismanner, water tends to hinder efficient heating of the formation. Forexample, a large amount of energy may be required to evaporate waterfrom a coal formation. Thus, an initial rate of temperature increase maybe reduced by the presence of water in the formation. Therefore,excessive amounts of heat and/or time may be required to heat aformation having a high moisture content to a temperature sufficient toallow pyrolysis of at least some of the hydrocarbons in the formation.In an embodiment, an in situ conversion process for coal may includeselecting a portion of the coal formation for treatment having aninitial moisture content of less than about 15% by weight (in someembodiments dewatering wells may be used to reduce the water content ofthe formation). Alternatively, an in situ conversion process for coalmay include selecting a portion of the coal formation for treatmenthaving an initial moisture content of less than about 10% by weight.

[0264] In an embodiment, a coal formation may be selected for treatmentbased on additional factors such as a thickness of coal layer within theformation and assessed liquid production content. For example, a coalformation may include multiple layers. Such layers may include coallayers, and also layers that may be coal free or have substantially lowamounts of coal. Each of the coal layers may have a thickness that mayvary depending on, for example, conditions under which the coal layerwas formed. Therefore, a coal formation will typically be selected fortreatment if that formation includes at least one coal layer having athickness sufficient for economical production of formation fluids. Aformation may also be chosen if the thickness of several layers that areclosely spaced together is sufficient for economical production offormation fluids.

[0265] In addition, a layer of a coal formation may be selected fortreatment based on a thickness of the coal layer, and/or a totalthickness of coal layers in a formation. For example, an in situconversion process for coal may include selecting and treating a layerof a coal formation having a thickness of greater than about 2 m, 3 m,and/or 5 m. In this manner, heat losses (as a fraction of total injectedheat) to layers formed above and below a layer of hydrocarbons may beless than such heat losses from a thin layer of coal. A process asdescribed herein, however, may also include selecting and treatinglayers that may include layers substantially free of coal and thinlayers of coal.

[0266] Each of the coal layers may also have a potential formation fluidyield that may vary depending on, for example, conditions under whichthe coal layer was formed, an amount of hydrocarbons in the layer,and/or a composition of hydrocarbons in the layer. A potential formationfluid yield may be measured, for example, by the Fischer Assay. TheFischer Assay is a standard method which involves heating a sample of acoal layer to approximately 500° C. in one hour, collecting productsproduced from the heated sample, and quantifying the amount of productsproduced. A sample of a coal layer may be obtained from a coal formationby a method such as coring or any other sample retrieval method.

[0267]FIG. 3 shows a schematic view of an embodiment of a portion of anin situ conversion system for treating a coal formation. Heat sources100 may be placed within at least a portion of the coal formation. Heatsources 100 may include, for example, electrical heaters such asinsulated conductors, conductor-in-conduit heaters, surface burners,flameless distributed combustors, and/or natural distributed combustors.Heat sources 100 may also include other types of heaters. Heat sources100 are configured to provide heat to at least a portion of a coalformation. Energy may be supplied to the heat sources 100 through supplylines 102. The supply lines may be structurally different depending onthe type of heat source or heat sources being used to heat theformation. Supply lines for heat sources may transmit electricity forelectrical heaters, may transport fuel for combustors, or may transportheat exchange fluid that is circulated within the formation.

[0268] Production wells 104 may be used to remove formation fluid fromthe formation. Formation fluid produced from the production wells 104may be transported through collection piping 106 to treatment facilities108. Formation fluids may also be produced from heat sources 100. Forexample, fluid may be produced from heat sources 100 to control pressurewithin the formation adjacent to the heat sources. Fluid produced fromheat sources 100 may be transported through tubing or piping to thecollection piping 106 or the produced fluid may be transported throughtubing or piping directly to the treatment facilities 108. The treatmentfacilities 108 may include separation units, reaction units, upgradingunits, fuel cells, turbines, storage vessels, and other systems andunits for processing produced formation fluids.

[0269] An in situ conversion system for treating coal may includedewatering wells 110 (wells shown with reference number 110 may, in someembodiments, be capture and/or isolation wells). Dewatering wells 110 orvacuum wells may be configured to remove and inhibit liquid water fromentering a portion of a coal formation to be heated, or to a formationbeing heated. A plurality of water wells may surround all or a portionof a formation to be heated. In the embodiment depicted in FIG. 3, thedewatering wells 110 are shown extending only along one side of heatsources 100, but dewatering wells typically encircle all heat sources100 used, or to be used, to heat the formation.

[0270] Dewatering wells 110 may be placed in one or more ringssurrounding selected portions of the formation. New dewatering wells mayneed to be installed as an area being treated by the in situ conversionprocess expands. An outermost row of dewatering wells may inhibit asignificant amount of water from flowing into the portion of formationthat is heated or to be heated. Water produced from the outermost row ofdewatering wells should be substantially clean, and may require littleor no treatment before being released. An innermost row of dewateringwells may inhibit water that bypasses the outermost row from flowinginto the portion of formation that is heated or to be heated. Theinnermost row of dewatering wells may also inhibit outward migration ofvapor from a heated portion of the formation into surrounding portionsof the formation. Water produced by the innermost row of dewateringwells may include some hydrocarbons. The water may need to be treatedbefore being released. Alternately, water with hydrocarbons may bestored and used to produce synthesis gas from a portion of formationduring a synthesis gas phase of the in situ conversion process. Thedewatering wells may reduce heat loss to surrounding portions of theformation, may increase production of vapors from the heated portion,and may inhibit contamination of a water table proximate the heatedportion of the formation.

[0271] In an alternative embodiment, a fluid (e.g., liquid or gas) maybe injected in the innermost row of wells, allowing a selected pressureto be maintained in or about the pyrolysis zone. Additionally, thisfluid may act as an isolation barrier between the outermost wells andthe pyrolysis fluids, thereby improving the efficiency of the dewateringwells.

[0272] The coal to be treated may be located under a large area. The insitu conversion system may be used to treat small portions of theformation, and other sections of the formation may be treated as timeprogresses. In an embodiment of a system for treating a coal formation,a field layout for 24 years of development may be divided into 24individual plots that represent individual drilling years. Each plot mayinclude 120 “tiles” (repeating matrix patterns) wherein each tile ismade of 6 rows by 20 columns. Each tile may include 1 production welland 12 or 18 heater wells. The heater wells may be placed in anequilateral triangle pattern with, for example, a well spacing of about12 m. Production wells may be located in centers of equilateraltriangles of heater wells, or the production wells may be locatedapproximately at a midpoint between two adjacent heater wells.

[0273] In certain embodiments, heat sources will be placed within aheater well formed within a coal formation. The heater well may includean opening through an overburden of the formation and into at least onesection of the formation. Alternatively, as shown in FIG. 3a, heaterwell 224 may include an opening in formation 222 that may have a shapesubstantially similar to a helix or spiral. A spiral configuration for aheater well may in some embodiments increase the transfer of heat fromthe heat source and/or allow the heat source to expand when heated,without buckling or other modes of failure. In some embodiments, such aheater well may also include a substantially straight section throughoverburden 220. Use of a straight heater well through the overburden maydecrease heat loss to the overburden.

[0274] In an alternative embodiment, as shown in FIG. 3b, heat sourcesmay be placed into heater well 224 that may include an opening information 222 having a shape substantially similar to a “U” (the “legs”of the “U” may be wider or more narrow depending on the embodimentsused). First portion 226 and third portion 228 of heater well 224 may bearranged substantially perpendicular to an upper surface of formation222. In addition, the first and the third portion of the heater well mayextend substantially vertically through overburden 220. Second portion230 of heater well 224 may be substantially parallel to the uppersurface of the formation.

[0275] In addition, multiple heat sources (e.g., 2, 3, 4, 5, 10 heatsources or more) may extend from a heater well in some situations. Forexample, as shown in FIG. 3c, heat sources 232, 234, and 236 may extendthrough overburden 220 into formation 222 from heater well 224. Suchsituations may occur when surface considerations (e.g., aesthetics,surface land use concerns, and/or unfavorable soil conditions near thesurface) make it desirable to concentrate the surface facilities infewer locations. For example, in areas where the soil is frozen and/ormarshy it may be more cost-effective to have surface facilities locatedin a more centralized location.

[0276] In certain embodiments a first portion of a heater well mayextend from a surface of the ground, through an overburden, and into acoal formation. A second portion of the heater well may include one ormore heater wells in the coal formation. The one or more heater wellsmay be disposed within the coal formation at various angles. In someembodiments, at least one of heater wells may be disposed substantiallyparallel to a boundary of the coal formation. In alternate embodiments,at least one of the heater wells may be substantially perpendicular tothe coal formation. In addition, one of the one or more heater wells maybe positioned at an angle between perpendicular and parallel to a layerin the formation.

[0277]FIG. 4 illustrates an embodiment of a coal formation 200 that maybe at a substantially near-horizontal angle with respect to an uppersurface of the ground 204. An angle of coal formation 200, however, mayvary. For example, coal formation 200 may be steeply dipping.Economically viable production of a steeply dipping coal formation maynot be possible using presently available mining methods. A relativelysteeply dipping coal formation, however, may be subjected to an in situconversion process as described herein. For example, a single set of gasproducing wells may be disposed near a top of a steeply dipping coalformation. Such a formation may be heated by heating a portion of theformation proximate a top of the coal formation and sequentially heatinglower sections of the coal formation. Gases may be produced from thecoal formation by transporting gases through the previously pyrolyzedhydrocarbons with minimal pressure loss.

[0278] In an embodiment, an in situ conversion process for coal mayinclude providing heat to at least a portion of a coal formation thatdips in sections. For example, a portion of the formation may include adip that may include a minimum depth of the portion. A production wellmay be located in the portion of the coal formation proximate theminimum depth. An additional production well may not be required in theportion. For example, as heat transfers through the coal formation andat least some hydrocarbons in the portion pyrolyze, pyrolyzation fluidsformed in the portion may travel through pyrolyzed sections of the coalformation to the production well. As described herein, increasedpermeability due to in situ treatment of a coal formation may increasetransfer of vapors through the treated portion of the formation.Therefore, a number of production wells required to produce a mixturefrom the formation may be reduced. Reducing the number of productionwells required for production may increase economic viability of an insitu conversion process.

[0279] In steeply dipping formations, directional drilling may be usedto form an opening for a heater well in the formation. Directionaldrilling may include drilling an opening in which the route/course ofthe opening may be planned before drilling. Such an opening may usuallybe drilled with rotary equipment. In directional drilling, aroute/course of an opening may be controlled by deflection wedges, etc.

[0280] Drilling heater well 202 may also include drilling an opening inthe formation with a drill equipped with a steerable motor and anaccelerometer that may be configured to follow coal formation 200. Forexample, a steerable motor may be configured to maintain a substantiallyconstant distance between heater well 202 and a boundary of coalformation 200 throughout drilling of the opening. Drilling of heaterwell 202 with the steerable motor and the accelerometer may berelatively economical.

[0281] Alternatively, geosteered drilling may be used to drill heaterwell 202 into coal formation 200. Geosteered drilling may includedetermining or estimating a distance from an edge of coal formation 200to heater well 202 with a sensor. The sensor may include, but may not belimited to, sensors that may be configured to determine a distance froman edge of coal formation 200 to heater well 202. In addition, such asensor may be configured to determine and monitor a variation in acharacteristic of the coal formation 200. Such sensors may include, butmay not be limited to, sensors that may be configured to measure acharacteristic of a hydrocarbon seam using resistance, gamma rays,acoustic pulses, and/or other devices. Geosteered drilling may alsoinclude forming an opening for a heater well with a drilling apparatusthat may include a steerable motor. The motor may be controlled tomaintain a predetermined distance from an edge of a coal formation. Inan additional embodiment, drilling of a heater well or any other well ina formation may also include sonic drilling.

[0282]FIG. 5 illustrates an embodiment of a plurality of heater wells210 formed in coal formation 212. Coal formation 212 may be a steeplydipping formation. One or more of the heater wells 210 may be formed inthe formation such that two or more of the heater wells aresubstantially parallel to each other, and/or such that at least oneheater well is substantially parallel to coal formation 212. Forexample, one or more of the heater wells 210 may be formed in coalformation 212 by a magnetic steering method. An example of a magneticsteering method is illustrated in U.S. Pat. No. 5,676,212 to Kuckes,which is incorporated by reference as if filly set forth herein.Magnetic steering may include drilling heater well 210 parallel to anadjacent heater well. The adjacent well may have been previouslydrilled. In addition, magnetic steering may include directing thedrilling by sensing and/or determining a magnetic field produced in anadjacent heater well. For example, the magnetic field may be produced inthe adjacent heater well by flowing a current through an insulatedcurrent-carrying wireline disposed in the adjacent heater well.Alternatively, one or more of the heater wells 210 may be formed by amethod as is otherwise described herein. A spacing between heater wells210 may be determined according to any of the embodiments describedherein.

[0283] In some embodiments, heated portion 310 may extend substantiallyradially from heat source 300, as shown in FIG. 6. For example, a widthof heated portion 310, in a direction extending radially from heatsource 300, may be about 0 m to about 10 m . A width of heated portion310 may vary, however, depending upon, for example, heat provided byheat source 300 and the characteristics of the formation. Heat providedby heat source 300 will typically transfer through the heated portion tocreate a temperature gradient within the heated portion. For example, atemperature proximate the heater well will generally be higher than atemperature proximate an outer lateral boundary of the heated portion. Atemperature gradient within the heated portion, however, may vary withinthe heated portion depending on, for example, the thermal conductivityof the formation.

[0284] As heat transfers through heated portion 310 of the coalformation, a temperature within at least a section of the heated portionmay be within a pyrolysis temperature range. In this manner, as the heattransfers away from the heat source, a front at which pyrolysis occurswill in many instances travel outward from the heat source. For example,heat from the heat source may be allowed to transfer into a selectedsection of the heated portion such that heat from the heat sourcepyrolyzes at least some of the hydrocarbons within the selected section.As such, pyrolysis may occur within selected section 315 of the heatedportion, and pyrolyzation fluids will be generated from hydrocarbons inthe selected section. An inner lateral boundary of selected section 315may be radially spaced from the heat source. For example, an innerlateral boundary of selected section 315 may be radially spaced from theheat source by about 0 m to about 1 m. In addition, selected section 315may have a width radially extending from the inner lateral boundary ofthe selected section. For example, a width of the selected section maybe at least approximately 1.5 m, at least approximately 2.4 m, or evenat least approximately 3.0 m. A width of the selected section, however,may also be greater than approximately 1.5 m and less than approximately10 m.

[0285] After pyrolyzation of hydrocarbons in a portion of the selectedsection is complete, a section of spent hydrocarbons 317 may begenerated proximate to the heat source.

[0286] In some embodiments, a plurality of heated portions may existwithin a unit of heat sources. A unit of heat sources refers to aminimal number of heat sources that form a template that may be repeatedto create a pattern of heat sources within the formation. The heatsources may be located within the formation such that superposition(overlapping) of heat produced from the heat sources is effective. Forexample, as illustrated in FIG. 7, transfer of heat from two or moreheat sources 330 results in superposition of heat 332 to be effectivewithin an area defined by the unit of heat sources. Superposition mayalso be effective within an interior of a region defined by two, three,four, five, six or more heat sources. For example, an area in whichsuperposition of heat 332 is effective includes an area to whichsignificant heat is transferred by two or more heat sources of the unitof heat sources. An area in which superposition of heat is effective mayvary depending upon, for example, the spacings between heat sources.

[0287] Superposition of heat may increase a temperature in at least aportion of the formation to a temperature sufficient for pyrolysis ofhydrocarbon within the portion. In this manner, superposition of heat332 tends to increase the amount of hydrocarbon in a formation that maybe pyrolyzed. As such, a plurality of areas that are within a pyrolysistemperature range may exist within the unit of heat sources. Theselected sections 334 may include areas at a pyrolysis temperature rangedue to heat transfer from only one heat source, as well as areas at apyrolysis temperature range due to superposition of heat.

[0288] In addition, a pattern of heat sources will often include aplurality of units of heat sources. There will typically be a pluralityof heated portions, as well as selected sections within the pattern ofheat sources. The plurality of heated portions and selected sections maybe configured as described herein. Superposition of heat within apattern of heat sources may decrease the time necessary to reachpyrolysis temperatures within the multitude of heated portions.Superposition of heat may allow for a relatively large spacing betweenadjacent heat sources, which may in turn provide a relatively slow rateof heating of the coal formation. In certain embodiments, superpositionof heat will also generate fluids substantially uniformly from a heatedportion of a coal formation.

[0289] In certain embodiments, a majority of pyrolysis fluids may beproduced when the selected section is within a range from about 0 m toabout 25 m from a heat source.

[0290] As shown in FIG. 3, in addition to heat sources 100, one or moreproduction wells 102 will typically be disposed within the portion ofthe coal formation. Production well 102 may be configured such that amixture that may include formation fluids may be produced through theproduction well. Production well 102 may also include a heat source. Inthis manner, the formation fluids may be maintained at a selectedtemperature throughout production, thereby allowing more or all of theformation fluids to be produced as vapors. Therefore high temperaturepumping of liquids from the production well may be reduced orsubstantially eliminated, which in turn decreases production costs.Providing heating at or through the production well tends to: (1)prevent condensation and/or refluxing of production fluid when suchproduction fluid is moving in the production well proximate to theoverburden, (2) increase heat input into the formation, and/or (3)increase formation permeability at or proximate the production well.

[0291] Because permeability and/or porosity increase in the heatedformation, produced vapors may flow considerable distances through theformation with relatively little pressure differential. Therefore, insome embodiments, production wells may be provided near an upper surfaceof the formation. Increases in permeability may result from a reductionof mass of the heated portion due to vaporization of water, removal ofhydrocarbons, and/or creation of fractures. In this manner, fluids maymore easily flow through the heated portion.

[0292] For example, fluid generated within a coal formation may move aconsiderable distance through the coal formation as a vapor. Such aconsiderable distance may include, for example, about 50 m to about 1000m. The vapor may have a relatively small pressure drop across theconsiderable distance due to the permeability of the heated portion ofthe formation. In addition, due to such permeability, a production wellmay only need to be provided in every other unit of heat sources orevery third, fourth, fifth, sixth units of heat sources. Furthermore, asshown in FIG. 4, production wells 206 may extend through a coalformation near the top of heated portion 208.

[0293] Embodiments of production well 102 may include valves configuredto alter, maintain, and/or control a pressure of at least a portion ofthe formation. Production wells may be cased wells that may haveproduction screens or perforated casings adjacent to production zones.In addition, the production wells may be surrounded by sand, gravel orother packing material adjacent to production zones. Furthermore,production wells 102 may be coupled to treatment section 108, as shownin FIG. 3. Treatment section 108 may include any of the surfacefacilities as described herein.

[0294] In addition, water pumping wells or vacuum wells may beconfigured to remove liquid water from a portion of a coal formation tobe heated. Water removed from the formation may be used on the surface,and/or monitored for water quality. For example, a plurality of waterwells may surround all or a portion of a formation to be heated. Theplurality of water wells may be configured in one or more ringssurrounding the portion of the formation. An outermost row of waterwells may inhibit a significant amount of water from flowing into theportion to be heated. An innermost row of water wells may inhibit waterthat bypasses the outermost row from flowing into the portion to beheated. The innermost row of water wells may also inhibit outwardmigration of vapor from a heated portion of the formation intosurrounding portions of the formation. In this manner, the water wellsmay reduce heat loss to surrounding portions of the formation, mayincrease production of vapors from the heated portion, and may inhibitcontamination of a water table proximate to the heated portion of theformation. In some embodiments pressure differences between successiverows of dewatering wells may be minimized (e.g., maintained or nearzero) to create a “no or low flow” boundary between rows.

[0295] In certain embodiments, wells initially used for one purpose maybe later used for one or more other purposes, thereby lowering projectcosts and/or decreasing the time required to perform certain tasks. Forinstance, production wells (and in some circumstances heater wells) mayinitially be used as dewatering wells (e.g., before heating is begunand/or when heating is initially started). In addition, in somecircumstances dewatering wells can later be used as production wells(and in some circumstances heater wells). As such, the dewatering wellsmay be placed and/or designed so that such wells can be later used asproduction wells and/or heater wells. The heater wells may be placedand/or designed so that such wells can be later used as production wellsand/or dewatering wells. The production wells may be placed and/ordesigned so that such wells can be later used as dewatering wells and/orheater wells. Similarly, injection wells may be wells that initiallywere used for other purposes (e.g., heating, production, dewatering,monitoring, etc.), and injection wells may later be used for otherpurposes. Similarly, monitoring wells may be wells that initially wereused for other purposes (e.g., heating, production, dewatering,injection, etc.), and monitoring wells may later be used for otherpurposes.

[0296]FIG. 8 illustrates a pattern of heat sources 400 and productionwells 402 that may be configured to treat a coal formation. Heat sources400 may be arranged in a unit of heat sources such as triangular pattern401. Heat sources 400, however, may be arranged in a variety of patternsincluding, but not limited to, squares, hexagons, and other polygons.The pattern may include a regular polygon to promote uniform heatingthrough at least the portion of the formation in which the heat sourcesare placed. The pattern may also be a line drive pattern. A line drivepattern is defined to include at least one linear array of heater wellsconfigured to heat at least a portion of a formation such that fluidsmay be produced from at least one production well. A line drive patternmay also include a first linear array of heater wells, a second lineararray of heater wells, and a production well or a linear array ofproduction wells between the first and second linear array of heaterwells.

[0297] A distance from a node of a polygon to a centroid of the polygonis smallest for a 3 sided polygon and increases with increasing numberof sides of the polygon. The distance from a node to the centroid for anequilateral triangle is (length/2)/(square root(3)/2) or 0.5774 timesthe length. For a square, the distance from a node to the centroid is(length/2)/(square root(2)/2) or 0.7071 times the length. For a hexagon,the distance from a node to the centroid is (length/2)/(½) or thelength. The difference in distance between a heat source and a mid pointto a second heat sources (length/2) and the distance from a heat sourceto the centroid for an equilateral pattern (0.5774 times the length) issignificantly less for the equilateral triangle pattern than for anyhigher order polygon pattern. The small difference means thatsuperposition of heat may develop more rapidly and that formationbetween heat sources may rise to a substantially more uniformtemperature using an equilateral triangle pattern rather than a higherorder polygon pattern.

[0298] Triangular patterns tend to provide more uniform heating to aportion of the formation in comparison to other patterns such as squaresand/or hexagons. Triangular patterns tend to provide faster heating to apredetermined temperature in comparison to other patterns such assquares and/or hexagons. Triangle patterns may also result in a smallvolume of the portion that is overheated. A plurality of units of heatsources such as triangular pattern 401 may be arranged substantiallyadjacent to each other to form a repetitive pattern of units over anarea of the formation. For example, triangular patterns 401 may bearranged substantially adjacent to each other in a repetitive pattern ofunits by inverting an orientation of adjacent triangles 401. Otherpatterns of heat sources 400 may also be arranged such that smallerpatterns may be disposed adjacent to each other to form larger patterns.

[0299] Production wells may be disposed in the formation in a repetitivepattern of units. In certain embodiments, production well 402 may bedisposed proximate to a center of every third triangle 401 arranged inthe pattern. Production well 402, however, may be disposed in everytriangle 401 or within just a few triangles. A production well may beplaced within every 13, 20, or 30 heater well triangles. For example, aratio of heat sources in the repetitive pattern of units to productionwells in the repetitive pattern of units may be more than approximately5 (e.g., more than 6, 7, 8, or 9). In addition, the placement ofproduction well 402 may vary depending on the heat generated by one ormore heat sources 400 and the characteristics of the formation (such aspermeability). Furthermore, three or more production wells may belocated within an area defined by a repetitive pattern of units. Forexample, as shown in FIG. 8, production wells 410 may be located withinan area defined by repetitive pattern of units 412. Production wells 410may be located in the formation in a unit of production wells. Forexample, the unit of production wells may be a triangular pattern.Production wells 410, however, may be disposed in another pattern withinrepetitive pattern of units 412.

[0300] In addition, one or more injection wells may be disposed within arepetitive pattern of units. The injection wells may be configured asdescribed herein. For example, as shown in FIG. 8, injection wells 414may be located within an area defined by repetitive pattern of units416. Injection wells 414 may also be located in the formation in a unitof injection wells. For example, the unit of injection wells may be atriangular pattern. Injection wells 414, however, may be disposed in anyother pattern as described herein. In certain embodiments, one or moreproduction wells and one or more injection wells may be disposed in arepetitive pattern of units. For example, as shown in FIG. 8, productionwells 418 and injection wells 420 may be located within an area definedby repetitive pattern of units 422. Production wells 418 may be locatedin the formation in a unit of production wells, which may be arranged ina first triangular pattern. In addition, injection wells 420 may belocated within the formation in a unit of production wells, which may bearranged in a second triangular pattern. The first triangular patternmay be substantially different than the second triangular pattern. Forexample, areas defined by the first and second triangular patterns maybe substantially different.

[0301] In addition, one or more monitoring wells may be disposed withina repetitive pattern of units. The monitoring wells may be configured asdescribed herein. For example, the wells may be configured with one ormore devices that measure a temperature, a pressure, and/or a propertyof a fluid. In some embodiments, logging tools may be placed inmonitoring well wellbores to measure properties within a formation. Thelogging tools may be moved to other monitoring well wellbores as needed.The monitoring well wellbores may be cased or uncased wellbores. Asshown in FIG. 8, monitoring wells 424 may be located within an areadefined by repetitive pattern of units 426. Monitoring wells 424 may belocated in the formation in a unit of monitoring wells, which may bearranged in a triangular pattern. Monitoring wells 424, however, may bedisposed in any of the other patterns as described herein withinrepetitive pattern of units 426.

[0302] It is to be understood that a geometrical pattern of heat sources400 and production wells 402 is described herein by example. A patternof heat sources and production wells will in many instances varydepending on, for example, the type of coal formation to be treated. Forexample, for relatively thin layers heating wells may be aligned alongone or more layers along strike or along dip. For relatively thicklayers, heat sources may be configured at an angle to one or more layers(e.g., orthogonally or diagonally).

[0303] A triangular pattern of heat sources may be configured to treat acoal formation having a thickness of about 10 meters or more. For athinner coal formation, e.g., about 10 meters thick or less, a lineand/or staggered line pattern of heat sources may be configured to treatthe coal formation.

[0304] For certain thinner formations, heating wells may be placedcloser to an edge of the coal formation (e.g., in a staggered lineinstead of line placed in the center of the layer) of the formation toincrease the amount of hydrocarbons produced per unit of energy input. Aportion of input heating energy may heat non-hydrocarbon containingformation, but the staggered pattern may allow superposition of heat toheat a majority of the coal formation to pyrolysis temperatures. If thethin formation is heated by placing one or more heater wells in theformation along a center of the thickness, a significant portion of thecoal formation may not be heated to pyrolysis temperatures. In someembodiments, placing heater wells closer to an edge of the formation mayincrease the volume of formation undergoing pyrolysis per unit of energyinput.

[0305] In addition, the location of production well 402 within a patternof heat sources 400 may be determined by, for example, a desired heatingrate of the coal formation, a heating rate of the heat sources, the typeof heat sources used, the type of coal formation (and its thickness),the composition of the coal formation, the desired composition to beproduced from the formation, and/or a desired production rate. Exactplacement of heater wells, production wells, etc. will depend onvariables specific to the formation (e.g., thickness of the layer,composition of the layer, etc.), project economics, etc. In certainembodiments heater wells may be substantially horizontal whileproduction wells may be vertical, or vice versa.

[0306] Any of the wells described herein may be aligned along dip orstrike, or oriented at an angle between dip and strike.

[0307] The spacing between heat sources may also vary depending on anumber of factors that may include, but are not limited to, the type ofa coal formation, the selected heating rate, and/or the selected averagetemperature to be obtained within the heated portion. For example, thespacing between heat sources may be within a range of about 5 m to about25 m. Alternatively, the spacing between heat sources may be within arange of about 8 m to about 15 m.

[0308] The spacing between heat sources may influence the composition offluids produced from a coal formation. In an embodiment, acomputer-implemented method may be used to determine optimum heat sourcespacings within a coal formation. For example, at least one property ofa portion of coal formation can usually be measured. The measuredproperty may include, but is not limited to, vitrinite reflectance,hydrogen content, atomic hydrogen to carbon ratio, oxygen content,atomic oxygen to carbon ratio, water content, thickness of the coalformation, and/or the amount of stratification of the coal formationinto separate layers of rock and hydrocarbons.

[0309] In certain embodiments a computer-implemented method may includeproviding at least one measured property to a computer system. One ormore sets of heat source spacings in the formation may also be providedto the computer system. For example, a spacing between heat sources maybe less than about 30 m. Alternatively, a spacing between heat sourcesmay be less than about 15 m. The method may also include determiningproperties of fluids produced from the portion as a function of time foreach set of heat source spacings. The produced fluids include, but arenot limited to, formation fluids such as pyrolyzation fluids andsynthesis gas. The determined properties may include, but are notlimited to, API gravity, carbon number distribution, olefin content,hydrogen content, carbon monoxide content, and/or carbon dioxidecontent. The determined set of properties of the produced fluid may becompared to a set of selected properties of a produced fluid. In thismanner, sets of properties that match the set of selected properties maybe determined. Furthermore, heat source spacings may be matched to heatsource spacings associated with desired properties.

[0310] Unit cell 404 will often include a number of heat sources 400disposed within a formation around each production well 402. An area ofunit cell 404 may be determined by midlines 406 that may be equidistantand perpendicular to a line connecting two production wells 402.Vertices 408 of the unit cell may be at the intersection of two midlines406 between production wells 402. Heat sources 400 may be disposed inany arrangement within the area of unit cell 404. For example, heatsources 400 may be located within the formation such that a distancebetween each heat source varies by less than approximately 10%, 20%, or30%. In addition, heat sources 400 may be disposed such that anapproximately equal space exists between each of the heat sources. Otherarrangements of heat sources 400 within unit cell 404, however, may beused depending on, for example, a heating rate of each of the heatsources. A ratio of heat sources 400 to production wells 402 may bedetermined by counting the number of heat sources 400 and productionwells 402 within unit cell 404, or over the total field.

[0311]FIG. 9 illustrates an embodiment of unit cell 404. Unit cell 404includes heat sources 400 and production wells 402. Unit cell 404 mayhave six full heat sources 400 a and six partial heat sources 400 b.Full heat sources 400 a may be closer to production well 402 thanpartial heat sources 400 b. In addition, an entirety of each of the fullheat sources 400 may be located within unit cell 404. Partial heatsources 400 b may be partially disposed within unit cell 404. Only aportion of heat source 400 b disposed within unit cell 404 may beconfigured to provide heat to a portion of a coal formation disposedwithin unit cell 404. A remaining portion of heat source 400 b disposedoutside of unit cell 404 may be configured to provide heat to aremaining portion of the coal formation outside of unit cell 404.Therefore, to determine a number of heat sources within unit cell 404partial heat source 400 b may be counted as one-half of full heatsources 400. In other unit cell embodiments, fractions other than ½(e.g. ⅓) may more accurately describe the amount of heat applied to aportion from a partial heat source.

[0312] The total number of heat sources 400 in unit cell 404 may includesix full heat sources 400 a that are each counted as one heat source,and six partial heat sources 400 b that are each counted as one half ofa heat source. Therefore, a ratio of heat sources 400 to productionwells 402 in unit cell 404 may be determined as 9:1. A ratio of heatsources to production wells may vary, however, depending on, forexample, the desired heating rate of the coal formation, the heatingrate of the heat sources, the type of heat source, the type of coalformation, the composition of coal formation, the desired composition ofthe produced fluid, and/or the desired production rate. Providing moreheat sources wells per unit area will allow faster heating of theselected portion and thus hastening the onset of production, howevermore heat sources will generally cost more money to install. Anappropriate ratio of heat sources to production wells may also includeratios greater than about 5:1, and ratios greater than about 7:1. Insome embodiments an appropriate ratio of heat sources to productionwells may be about 10:1, 20:1, 50:1 or greater. If larger ratios areused, then project costs tend to decrease since less wells and equipmentare needed.

[0313] A “selected section” would generally be the volume of formationthat is within a perimeter defined by the location of the outermost heatsources (assuming that the formation is viewed from above). For example,if four heat sources were located in a single square pattern with anarea of about 100 m² (with each source located at a corner of thesquare), and if the formation had an average thickness of approximately5 m across this area, then the selected section would be a volume ofabout 500 m³ (i.e., the area multiplied by the average formationthickness across the area). In many commercial applications, it isenvisioned that many (e.g., hundreds or thousands) heat sources would beadjacent to each other to heat a selected section, and therefore in suchcases only the outermost (i.e., the “edge”) heat sources would definethe perimeter of the selected section.

[0314] A heat source may include, but is not limited to, an electricheater or a combustion heater. The electric heater may include aninsulated conductor, an elongated member disposed in the opening, and/ora conductor disposed in a conduit. Such an electric heater may beconfigured according to any of the embodiments described herein.

[0315] In an embodiment, a coal formation may be heated with a naturaldistributed combustor system located in the formation. The generatedheat may be allowed to transfer to a selected section of the formationto heat it.

[0316] A temperature sufficient to support oxidation may be, forexample, at least about 200° C. or 250° C. The temperature sufficient tosupport oxidation will tend to vary, however, depending on, for example,a composition of the hydrocarbons in the coal formation, water contentof the formation, and/or type and amount of oxidant. Some water may beremoved from the formation prior to heating. For example, the water maybe pumped from the formation by dewatering wells. The heated portion ofthe formation may be near or substantially adjacent to an opening in thecoal formation. The opening in the formation may be a heater well formedin the formation. The heater well may be formed as in any of theembodiments described herein. The heated portion of the coal formationmay extend radially from the opening to a width of about 0.3 m to about1.2 m. The width, however, may also be less than about 0.9 m. A width ofthe heated portion may vary. In certain embodiments the variance willdepend on, for example, a width necessary to generate sufficient heatduring oxidation of carbon to maintain the oxidation reaction withoutproviding heat from an additional heat source.

[0317] After the portion of the formation reaches a temperaturesufficient to support oxidation, an oxidizing fluid may be provided intothe opening to oxidize at least a portion of the hydrocarbons at areaction zone, or a heat source zone, within the formation. Oxidation ofthe hydrocarbons will generate heat at the reaction zone. The generatedheat will in most embodiments transfer from the reaction zone to apyrolysis zone in the formation. In certain embodiments the generatedheat will transfer at a rate between about 650 watts per meter asmeasured along a depth of the reaction zone, and/or 1650 watts per meteras measured along a depth of the reaction zone. Upon oxidation of atleast some of the hydrocarbons in the formation, energy supplied to theheater for initially heating may be reduced or may be turned off. Assuch, energy input costs may be significantly reduced, thereby providinga significantly more efficient system for heating the formation.

[0318] In an embodiment, a conduit may be disposed in the opening toprovide the oxidizing fluid into the opening. The conduit may have floworifices, or other flow control mechanisms (i.e., slits, venturi meters,valves, etc.) to allow the oxidizing fluid to enter the opening. Theterm “orifices” includes openings having a wide variety ofcross-sectional shapes including, but not limited to, circles, ovals,squares, rectangles, triangles, slits, or other regular or irregularshapes. The flow orifices may be critical flow orifices in someembodiments. The flow orifices may be configured to provide asubstantially constant flow of oxidizing fluid into the opening,regardless of the pressure in the opening.

[0319] In some embodiments, the number of flow orifices, which may beformed in or coupled to the conduit, may be limited by the diameter ofthe orifices and a desired spacing between orifices for a length of theconduit. For example, as the diameter of the orifices decreases, thenumber of flow orifices may increase, and vice versa. In addition, asthe desired spacing increases, the number of flow orifices may decrease,and vice versa. The diameter of the orifices may be determined by, forexample, a pressure in the conduit and/or a desired flow rate throughthe orifices. For example, for a flow rate of about 1.7 standard cubicmeters per minute and a pressure of about 7 bar absolute, an orificediameter may be about 1.3 mm with a spacing between orifices of about 2m.

[0320] Smaller diameter orifices may plug more easily than largerdiameter orifices due to, for example, contamination of fluid in theopening or solid deposition within or proximate to the orifices. In someembodiments, the number and diameter of the orifices can be chosen suchthat a more even or nearly uniform heating profile will be obtainedalong a depth of the formation within the opening. For example, a depthof a heated formation that is intended to have an approximately uniformheating profile may be greater than about 300 m, or even greater thanabout 600 m. Such a depth may vary, however, depending on, for example,a type of formation to be heated and/or a desired production rate.

[0321] In some embodiments, flow orifices may be disposed in a helicalpattern around the conduit within the opening. The flow orifices may bespaced by about 0.3 m to about 3 m between orifices in the helicalpattern. In some embodiments, the spacing may be about 1 m to about 2 mor, for example, about 1.5 m.

[0322] The flow of the oxidizing fluid into the opening may becontrolled such that a rate of oxidation at the reaction zone iscontrolled. Transfer of heat between incoming oxidant and outgoingoxidation products may heat the oxidizing fluid. The transfer of heatmay also maintain the conduit below a maximum operating temperature ofthe conduit.

[0323]FIG. 10 illustrates an embodiment of a natural distributedcombustor configured to heat a coal formation. Conduit 512 may be placedinto opening 514 in formation 516. Conduit 512 may have inner conduit513. Oxidizing fluid source 508 may provide oxidizing fluid 517 intoinner conduit 513. Inner conduit 513 may have critical flow orifices 515along its length. Critical flow orifices 515 may be disposed in ahelical pattern (or any other pattern) along a length of inner conduit513 in opening 514. For example, critical flow orifices 515 may bearranged in a helical pattern with a distance of about 1 m to about 2.5m between adjacent orifices. Critical flow orifices 515 may be furtherconfigured as described herein. Inner conduit 513 may be sealed at thebottom. Oxidizing fluid 517 may be provided into opening 514 throughcritical flow orifices 515 of inner conduit 513.

[0324] Critical flow orifices 515 may be designed such thatsubstantially the same flow rate of oxidizing fluid 517 may be providedthrough each critical flow orifice. Critical flow orifices 515 may alsoprovide substantially uniform flow of oxidizing fluid 517 along a lengthof conduit 512. Such flow may provide substantially uniform heating offormation 516 along the length of conduit 512.

[0325] Packing material 542 may enclose conduit 512 in overburden 540 ofthe formation. Packing material 542 may substantially inhibit flow offluids from opening 514 to surface 550. Packing material 542 may includeany material configurable to inhibit flow of fluids to surface 550 suchas cement, sand, and/or gravel. Typically a conduit or an opening in thepacking remains to provide a path for oxidation products to reach thesurface.

[0326] Oxidation products 519 typically enter conduit 512 from opening514. Oxidation products 519 may include carbon dioxide, oxides ofnitrogen, oxides of sulfur, carbon monoxide, and/or other productsresulting from a reaction of oxygen with hydrocarbons and/or carbon.Oxidation products 519 may be removed through conduit 512 to surface550. Oxidation product 519 may flow along a face of reaction zone 524 inopening 514 until proximate an upper end of opening 514 where oxidationproduct 519 may flow into conduit 512. Oxidation products 519 may alsobe removed through one or more conduits disposed in opening 514 and/orin formation 516. For example, oxidation products 519 may be removedthrough a second conduit disposed in opening 514. Removing oxidationproducts 519 through a conduit may substantially inhibit oxidationproducts 519 from flowing to a production well disposed in formation516. Critical flow orifices 515 may also be configured to substantiallyinhibit oxidation products 519 from entering inner conduit 513.

[0327] A flow rate of oxidation product 519 may be balanced with a flowrate of oxidizing fluid 517 such that a substantially constant pressureis maintained within opening 514. For a 100 m length of heated section,a flow rate of oxidizing fluid may be between about 0.5 standard cubicmeters per minute to about 5 standard cubic meters per minute, or about1.0 standard cubic meters per minute to about 4.0 standard cubic metersper minute, or, for example, about 1.7 standard cubic meters per minute.A flow rate of oxidizing fluid into the formation may be incrementallyincreased during use to accommodate expansion of the reaction zone. Apressure in the opening may be, for example, about 8 bar absolute.Oxidizing fluid 517 may oxidize at least a portion of the hydrocarbonsin heated portion 518 of coal formation 516 at reaction zone 524. Heatedportion 518 may have been initially heated to a temperature sufficientto support oxidation by an electric heater, as shown in FIG. 14, or byany other suitable system or method described herein. In someembodiments, an electric heater may be placed inside or strapped to theoutside of conduit 513.

[0328] In certain embodiments it is beneficial to control the pressurewithin the opening 514 such that oxidation product and/or oxidationfluids are inhibited from flowing into the pyrolysis zone of theformation. In some instances pressure within opening 514 will bebalanced with pressure within the formation to do so.

[0329] Although the heat from the oxidation is transferred to theformation, oxidation product 519 (and excess oxidation fluid such asair) may be substantially inhibited from flowing through the formationand/or to a production well within formation 516. Instead oxidationproduct 519 (and excess oxidation fluid) is removed (e.g., through aconduit such as conduit 512) as is described herein. In this manner,heat is transferred to the formation from the oxidation but exposure ofthe pyrolysis zone with oxidation product 519 and/or oxidation fluid maybe substantially inhibited and/or prevented.

[0330] In certain embodiments, some pyrolysis product near the reactionzone 524 may also be oxidized in reaction zone 524 in addition to thecarbon. Oxidation of the pyrolysis product in reaction zone 524 mayprovide additional heating of formation 516. When such oxidation ofpyrolysis product occurs, it is desirable that oxidation product fromsuch oxidation be removed (e.g., through a conduit such as conduit 512)near the reaction zone as is described herein, thereby inhibitingcontamination of other pyrolysis product in the formation with oxidationproduct.

[0331] Conduit 512 may be configured to remove oxidation product 519from opening 514 in formation 516. As such, oxidizing fluid 517 in innerconduit 513 may be heated by heat exchange in overburden section 540from oxidation product 519 in conduit 512. Oxidation product 519 may becooled by transferring heat to oxidizing fluid 517. In this manner,oxidation of hydrocarbons within formation 516 may be more thermallyefficient.

[0332] Oxidizing fluid 517 may transport through reaction zone 524, orheat source zone, by gas phase diffusion and/or convection. Diffusion ofoxidizing fluid 517 through reaction zone 524 may be more efficient atthe relatively high temperatures of oxidation. Diffusion of oxidizingfluid 517 may inhibit development of localized overheating and fingeringin the formation. Diffusion of oxidizing fluid 517 through formation 516is generally a mass transfer process. In the absence of an externalforce, a rate of diffusion for oxidizing fluid 517 may depend uponconcentration, pressure, and/or temperature of oxidizing fluid 517within formation 516. The rate of diffusion may also depend upon thediffusion coefficient of oxidizing fluid 517 through formation 516. Thediffusion coefficient may be determined by measurement or calculationbased on the kinetic theory of gases. In general, random motion ofoxidizing fluid 517 may transfer oxidizing fluid 517 through formation516 from a region of high concentration to a region of lowconcentration.

[0333] With time, reaction zone 524 may slowly extend radially togreater diameters from opening 514 as hydrocarbons are oxidized.Reaction zone 524 may, in many embodiments, maintain a relativelyconstant width. For example, reaction zone 524 may extend radially at arate of less than about 0.91 m per year for a coal formation. Forexample, for a coal formation, reaction zone 524 may extend radially ata rate between about 0.5 m per year to about 1 m per year. Reaction zone524 may extend at slower rates for hydrocarbon rich formations sincemore hydrocarbons per volume are available for combustion in thehydrocarbon rich formations.

[0334] A flow rate of oxidizing fluid 517 into opening 514 may beincreased as a diameter of reaction zone 524 increases to maintain therate of oxidation per unit volume at a substantially steady state. Thus,a temperature within reaction zone 524 may be maintained substantiallyconstant in some embodiments. The temperature within reaction zone 524may be between about 650° C. to about 900° C. or, for example, about760° C. The temperature may be maintained below a temperature thatresults in production of oxides of nitrogen (NO_(x)).

[0335] The temperature within reaction zone 524 may vary depending on,for example, a desired heating rate of selected section 526. Thetemperature within reaction zone 524 may be increased or decreased byincreasing or decreasing, respectively, a flow rate of oxidizing fluid517 into opening 514. A temperature of conduit 512, inner conduit 513,and/or any metallurgical materials within opening 514 typically will notexceed a maximum operating temperature of the material. Maintaining thetemperature below the maximum operating temperature of a material mayinhibit excessive deformation and/or corrosion of the material.

[0336] An increase in the diameter of reaction zone 524 may allow forrelatively rapid heating of the coal formation 516. As the diameter ofreaction zone 524 increases, an amount of heat generated per time inreaction zone 524 may also increase. Increasing an amount of heatgenerated per time in the reaction zone will in many instances increasethe heating rate of the formation 516 over a period of time, evenwithout increasing the temperature in the reaction zone or thetemperature at conduit 513. Thus, increased heating may be achieved overtime without installing additional heat sources, and without increasingtemperatures adjacent to wellbores. In some embodiments the heatingrates may be increased while allowing the temperatures to decrease(allowing temperatures to decrease may often lengthen the life of theequipment used).

[0337] By utilizing the carbon in the formation as a fuel, the naturaldistributed combustor may save significantly on energy costs. Thus, aneconomical process may be provided for heating formations that mayotherwise be economically unsuitable for heating by other methods. Also,fewer heaters may be placed over an extended area of formation 516. Thismay provide for a reduced equipment cost associated with heating theformation 516.

[0338] The heat generated at reaction zone 524 may transfer by thermalconduction to selected section 526 of formation 516. In addition,generated heat may transfer from a reaction zone to the selected sectionto a lesser extent by convection heat transfer. Selected section 526,sometimes referred to herein as the “pyrolysis zone,” may besubstantially adjacent to reaction zone 524. Since oxidation product(and excess oxidation fluid such as air) is typically removed from thereaction zone, the pyrolysis zone can receive heat from the reactionzone without being exposed to oxidation product, or oxidants, that arein the reaction zone. Oxidation product and/or oxidation fluids maycause the formation of undesirable formation products if they arepresent in the pyrolysis zone. For example, in certain embodiments it isdesirable to conduct pyrolysis in a reducing environment. Thus, it isoften usefull to allow heat to transfer from the reaction zone to thepyrolysis zone while inhibiting or preventing oxidation product and/oroxidation fluid from reaching the pyrolysis zone.

[0339] Pyrolysis of hydrocarbons, or other heat-controlled processes,may take place in heated selected section 526. Selected section 526 maybe at a temperature between about 270° C. to about 400° C. forpyrolysis. The temperature of selected section 526 may be increased byheat transfer from reaction zone 524. A rate of temperature increase maybe selected as in any of the embodiments described herein. A temperaturein formation 516, selected section 526, and/or reaction zone 524 may becontrolled such that production of oxides of nitrogen may besubstantially inhibited. Oxides of nitrogen are often produced attemperatures above about 1200° C.

[0340] A temperature within opening 514 may be monitored with athermocouple disposed in opening 514. The temperature within opening 514may be monitored such that a temperature may be maintained within aselected range. The selected range may vary, depending on, for example,a desired heating rate of formation 516. A temperature may be maintainedwithin a selected range by increasing or decreasing a flow rate ofoxidizing fluid 517. For example, if a temperature within opening 514falls below a selected range of temperatures, the flow rate of oxidizingfluid 517 may be increased to increase the combustion and therebyincrease the temperature within opening 514. Alternatively, athermocouple may be disposed on conduit 512 and/or disposed on a face ofreaction zone 524, and a temperature may be monitored accordingly.

[0341] In certain embodiments one or more natural distributed combustorsmay be placed along strike and/or horizontally. Doing so tends to reducepressure differentials along the heated length of the well, therebytending to promote more uniform heating and improved control.

[0342] In some embodiments, a presence of air or molecular oxygen, O₂,in oxidation product 519 may be monitored. Alternatively, an amount ofnitrogen, carbon monoxide, carbon dioxide, oxides of nitrogen, oxides ofsulfur, etc. may be monitored in oxidation product 519. Monitoring thecomposition and/or quantity of oxidation product 519 may be useful forheat balances, for process diagnostics, process control, etc.

[0343]FIG. 11 illustrates an embodiment of a section of overburden witha natural distributed combustor as described in FIG. 10. Overburdencasing 541 may be disposed in overburden 540 of formation 516.Overburden casing 541 may be substantially surrounded by materials(e.g., an insulating material such as cement) that may substantiallyinhibit heating of overburden 540. Overburden casing 541 may be made ofa metal material such as, but not limited to, carbon steel.

[0344] Overburden casing may be placed in reinforcing material 544 inoverburden 540. Reinforcing material 544 may be, for example, cement,sand, concrete, etc. Packing material 542 may be disposed betweenoverburden casing 541 and opening 514 in the formation. Packing material542 may be any substantially non-porous material (e.g., cement,concrete, grout, etc.). Packing material 542 may inhibit flow of fluidoutside of conduit 512 and between opening 514 and surface 550. Innerconduit 513 may provide a fluid into opening 514 in formation 516.Conduit 512 may remove a combustion product (or excess oxidation fluid)from opening 514 in formation 516. Diameter of conduit 512 may bedetermined by an amount of the combustion product produced by oxidationin the natural distributed combustor. For example, a larger diameter maybe required for a greater amount of exhaust product produced by thenatural distributed combustor heater.

[0345] In an alternative embodiment, at least a portion of the formationmay be heated to a temperature such that at least a portion of the coalformation may be converted to coke and/or char. Coke and/or char may beformed at temperatures above about 400° C. and at a high heating rate(e.g., above about 10° C./day). In the presence of an oxidizing fluid,the coke or char will oxidize. Heat may be generated from the oxidationof coke or char as in any of the embodiments described herein.

[0346]FIG. 12 illustrates an embodiment of a natural distributedcombustor heater. Insulated conductor 562 may be coupled to conduit 532and placed in opening 514 in formation 516. Insulated conductor 562 maybe disposed internal to conduit 532 (thereby allowing retrieval of theinsulated conductor 562), or, alternately, coupled to an externalsurface of conduit 532. Such insulating material may include, forexample, minerals, ceramics, etc. Conduit 532 may have critical floworifices 515 disposed along its length within opening 514. Critical floworifices 515 may be configured as described herein. Electrical currentmay be applied to insulated conductor 562 to generate radiant heat inopening 514. Conduit 532 may be configured to serve as a return forcurrent. Insulated conductor 562 may be configured to heat portion 518of the formation to a temperature sufficient to support oxidation ofhydrocarbons. Portion 518, reaction zone 524, and selected section 526may have characteristics as described herein. Such a temperature mayinclude temperatures as described herein.

[0347] Oxidizing fluid source 508 may provide oxidizing fluid intoconduit 532. Oxidizing fluid may be provided into opening 514 throughcritical flow orifices 515 in conduit 532. Oxidizing fluid may oxidizeat least a portion of the coal formation in at reaction zone 524.Reaction zone 524 may have characteristics as described herein. Heatgenerated at reaction zone 524 may transfer heat to selected section526, for example, by convection, radiation, and/or conduction. Oxidationproduct may be removed through a separate conduit placed in opening 514or through an opening 543 in overburden casing 541. The separate conduitmay be configured as described herein. Packing material 542 andreinforcing material 544 may be configured as described herein.

[0348]FIG. 13 illustrates an embodiment of a natural distributedcombustor heater with an added fuel conduit. Fuel conduit 536 may bedisposed into opening 514. It may be disposed substantially adjacent toconduit 533 in certain embodiments. Fuel conduit 536 may have criticalflow orifices 535 along its length within opening 514. Conduit 533 mayhave critical flow orifices 515 along its length within opening 514.Critical flow orifices 515 may be configured as described herein.Critical flow orifices 535 and critical flow orifices 515 may be placedon fuel conduit 536 and conduit 533, respectively, such that a fuelfluid provided through fuel conduit 536 and an oxidizing fluid providedthrough conduit 533 may not substantially heat fuel conduit 536 and/orconduit 533 upon reaction. For example, the fuel fluid and the oxidizingfluid may react upon contact with each other, thereby producing heatfrom the reaction. The heat from this reaction may heat fuel conduit 536and/or conduit 533 to a temperature sufficient to substantially beginmelting metallurgical materials in fuel conduit 536 and/or conduit 533if the reaction takes place proximate to fuel conduit 536 and/or conduit533. Therefore, a design for disposing critical flow orifices 535 onfuel conduit 536 and critical flow orifices 515 on conduit 533 may beprovided such that the fuel fluid and the oxidizing fluid may notsubstantially react proximate to the conduits. For example, conduits 536and 533 may be mechanically coupled such that orifices are oriented inopposite directions, and such that the orifices face the formation 516.

[0349] Reaction of the fuel fluid and the oxidizing fluid may produceheat. The fuel fluid and the oxidizing fluid may have characteristicsherein. The fuel fluid may be, for example, natural gas, ethane,hydrogen or synthesis gas that is generated in the in situ process inanother part of the formation. The produced heat may be configured toheat portion 518 to a temperature sufficient to support oxidation ofhydrocarbons. Upon heating of portion 518 to a temperature sufficient tosupport oxidation, a flow of fuel fluid into opening 514 may be turneddown or may be turned off. Alternatively, the supply of fuel may becontinued throughout the heating of the formation, thereby utilizing thestored heat in the carbon to maintain the temperature in opening 514above the autoignition temperature of the fuel.

[0350] The oxidizing fluid may oxidize at least a portion of thehydrocarbons at reaction zone 524. Generated heat will transfer heat toselected section 526, for example, by radiation, convection, and/orconduction. An oxidation product may be removed through a separateconduit placed in opening 514 or through an opening 543 in overburdencasing 541. Packing material 542 and reinforcing material 544 may beconfigured as herein.

[0351]FIG. 14 illustrates an embodiment of a system configured to heat acoal formation. Electric heater 510 may be disposed within opening 514in coal formation 516. Opening 514 may be formed through overburden 540into formation 516. Opening 514 may be at least about 5 cm in diameter.Opening 514 may, as an example, have a diameter of about 13 cm. Electricheater 510 may heat at least portion 518 of coal formation 516 to atemperature sufficient to support oxidation (e.g., about 260° C.).Portion 518 may have a width of about 1 m. An oxidizing fluid (e.g.,liquid or gas) may be provided into the opening through conduit 512 orany other appropriate fluid transfer mechanism. Conduit 512 may havecritical flow orifices 515 disposed along a length of the conduit.Critical flow orifices 515 may be configured as described herein.

[0352] For example, conduit 512 may be a pipe or tube configured toprovide the oxidizing fluid into opening 514 from oxidizing fluid source508. For example, conduit 512 may be a stainless steel tube. Theoxidizing fluid may include air or any other oxygen containing fluid(e.g., hydrogen peroxide, oxides of nitrogen, ozone). Mixtures ofoxidizing fluids may be used. An oxidizing fluid mixture may include,for example, a fluid including fifty percent oxygen and fifty percentnitrogen. The oxidizing fluid may also, in some embodiments, includecompounds that release oxygen when heated as described herein such ashydrogen peroxide. The oxidizing fluid may oxidize at least a portion ofthe hydrocarbons in the formation.

[0353] In some embodiments, a heat exchanger disposed external to theformation may be configured to heat the oxidizing fluid. The heatedoxidizing fluid may be provided into the opening from (directly orindirectly) the heat exchanger. For example, the heated oxidizing fluidmay be provided from the heat exchanger into the opening through aconduit disposed in the opening and coupled to the heat exchanger. Insome embodiments the conduit may be a stainless steel tube. The heatedoxidizing fluid may be configured to heat, or at least contribute to theheating of, at least a portion of the formation to a temperaturesufficient to support oxidation of hydrocarbons. After the heatedportion reaches such a temperature, heating of the oxidizing fluid inthe heat exchanger may be reduced or may be turned off.

[0354]FIG. 15 illustrates another embodiment of a system configured toheat a coal formation. Heat exchanger 520 may be disposed external toopening 514 in coal formation 516. Opening 514 may be formed throughoverburden 540 into formation 516. Heat exchanger 520 may provide heatfrom another surface process, or it may include a heater (e.g., anelectric or combustion heater). Oxidizing fluid source 508 may providean oxidizing fluid to heat exchanger 520. Heat exchanger 520 may heat anoxidizing fluid (e.g., above 200° C. or a temperature sufficient tosupport oxidation of hydrocarbons). The heated oxidizing fluid may beprovided into opening 514 through conduit 521. Conduit 521 may havecritical flow orifices 515 disposed along a length of the conduit.Critical flow orifices 515 may be configured as described herein. Theheated oxidizing fluid may heat, or at least contribute to the heatingof, at least portion 518 of the formation to a temperature sufficient tosupport oxidation of hydrocarbons. The oxidizing fluid may oxidize atleast a portion of the hydrocarbons in the formation.

[0355] In another embodiment, a fuel fluid may be oxidized in a heaterlocated external to a coal formation. The fuel fluid may be oxidizedwith an oxidizing fluid in the heater. As an example, the heater may bea flame-ignited heater. A fuel fluid may include any fluid configured toreact with oxygen. An example of a fuel fluid may be methane, ethane,propane, or any other hydrocarbon or hydrogen and synthesis gas. Theoxidized fuel fluid may be provided into the opening from the heaterthrough a conduit and return to the surface through another conduit inthe overburden. The conduits may be coupled within the overburden. Insome embodiments, the conduits may be concentrically placed. Theoxidized fuel fluid may be configured to heat, or at least contribute tothe heating of, at least a portion of the formation to a temperaturesufficient to support oxidation of hydrocarbons. Upon reaching such atemperature, the oxidized fuel fluid may be replaced with an oxidizingfluid. The oxidizing fluid may oxidize at least a portion of thehydrocarbons at a reaction zone within the formation.

[0356] An electric heater may be configured to heat a portion of thecoal formation to a temperature sufficient to support oxidation ofhydrocarbons. The portion may be proximate to or substantially adjacentto the opening in the formation. The portion may also radially extend awidth of less than approximately 1 m from the opening. A width of theportion may vary, however, depending on, for example, a power suppliedto the heater. An oxidizing fluid may be provided to the opening foroxidation of hydrocarbons. Oxidation of the hydrocarbons may beconfigured to heat the coal formation in a process of naturaldistributed combustion. Electrical current applied to the electricheater may subsequently be reduced or may be turned off. Thus, naturaldistributed combustion may be configured, in conjunction with anelectric heater, to provide a reduced input energy cost method to heatthe coal formation compared to using an electric heater.

[0357] An insulated conductor heater may be a heater element of a heatsource. In an embodiment of an insulated conductor heater, the insulatedconductor heater is a mineral insulated cable or rod. An insulatedconductor heater may be placed in an opening in a coal formation. Theinsulated conductor heater may be placed in an uncased opening in thecoal formation. Placing the heater in an uncased opening in the coalformation may allow heat transfer from the heater to the formation byradiation, as well as, conduction. In addition, using an uncased openingmay also allow retrieval of the heater from the well, if necessary, andmay eliminate the cost of the casing. Alternately, the insulatedconductor heater may be placed within a casing in the formation; may becemented within the formation; or may be packed in an opening with sand,gravel, or other fill material. The insulated conductor heater may besupported on a support member positioned within the opening. The supportmember may be a cable, rod, or a conduit (e.g., a pipe). The supportmember may be made of a metal, ceramic, inorganic material, orcombinations thereof. Portions of a support member may be exposed toformation fluids and heat during use, so the support member may bechemically resistant and thermally resistant.

[0358] Ties, spot welds and/or other types of connectors may be used tocouple the insulated conductor heater to the support member at variouslocations along a length of the insulated conductor heater. The supportmember may be attached to a wellhead at an upper surface of theformation. In an alternate embodiment of an insulated conductor heater,the insulated conductor heater is designed to have sufficient structuralstrength so that a support member is not needed. The insulated conductorheater will in many instances have some flexibility to inhibit thermalexpansion damage when heated or cooled.

[0359] In certain embodiments, insulated conductor heaters may be placedin wellbores without support members and/or centralizers. This can beaccomplished for heaters if the insulated conductor has a suitablecombination of temperature and corrosion resistance, creep strength,length, thickness (diameter), and metallurgy that will inhibit failureof the insulated conductor during use. In an embodiment, insulatedconductors that are heated to working temperature of about 700° C. areless than about 150 meters in length, are made of 310 stainless steel,and may be used without support members.

[0360]FIG. 16 depicts a perspective view of an end portion of anembodiment of an insulated conductor heater 562. An insulated conductorheater may have any desired cross sectional shape, such as, but notlimited to round (as shown in FIG. 16), triangular, ellipsoidal,rectangular, hexagonal or irregular shape. An insulated conductor heatermay include conductor 575, electrical insulation 576 and sheath 577. Theconductor 575 may resistively heat when an electrical current passesthrough the conductor. An alternating or direct current may be used toheat the conductor 575. In an embodiment, a 60 cycle AC current may beused.

[0361] In some embodiments, the electrical insulation 576 may inhibitcurrent leakage and may inhibit arcing to the sheath 577. The electricalinsulation 576 may also thermally conduct heat generated in theconductor 575 to the sheath 577. The sheath 577 may radiate or conductheat to the formation. An insulated conductor heater 562 may be 1000 mor more in length. In an embodiment of an insulated conductor heater,the insulated conductor heater 562 may have a length from about 15 m toabout 950 m. Longer or shorter insulated conductors may also be used tomeet specific application needs. In embodiments of insulated conductorheaters, purchased insulated conductor heaters have lengths of about 100m to 500 m (e.g., 230 m). In certain embodiments, dimensions of sheathsand/or conductors of an insulated conductor may be formed so that theinsulated conductors have enough strength to be self supporting even atupper working temperatures. Such insulated cables may be suspended fromwellheads or supports positioned near an interface between an overburdenand a coal formation without the need for support members extending intothe hydrocarbon formation along with the insulated conductors.

[0362] In an embodiment, a higher frequency current may be used to takeadvantage of the skin effect in certain metals. In some embodiments, a60 cycle AC current may be used in combination with conductors made ofmetals that exhibit pronounced skin effects. For example, ferromagneticmetals like iron alloys and nickel may exhibit a skin effect. The skineffect confines the current to a region close to the outer surface ofthe conductor, thereby effectively increasing the resistance of theconductor. A higher resistance may be desired to decrease the operatingcurrent, minimize ohmic losses in surface cables, and also minimize thecost of surface facilities.

[0363] As illustrated in FIG. 17, an insulated conductor heater 562 willin many instances be designed to operate at a power level of up to about1650 watts/meter. The insulated conductor heater 562 may typicallyoperate at a power level between about 500 watts/meter and about 1150watts/meter when heating a formation. The insulated conductor heater 562may be designed so that a maximum voltage level at a typical operatingtemperature does not cause substantial thermal and/or electricalbreakdown of electrical insulation 576. The insulated conductor heater562 may be designed so that the sheath 577 does not exceed a temperaturethat will result in a significant reduction in corrosion resistanceproperties of the sheath material.

[0364] In an embodiment of an insulated conductor heater 562, theconductor 575 may be designed to reach temperatures within a rangebetween about 650° C. to about 870° C., and the sheath 577 may bedesigned to reach temperatures within a range between about 535° C. toabout 760° C. Insulated conductors having other operating ranges may beformed to meet specific operational requirements. In an embodiment of aninsulated conductor heater 562, the conductor 575 is designed to operateat about 760° C., the sheath 577 is designed to operate at about 650°C., and the insulated conductor heater is designed to dissipate about820 watts/meter.

[0365] An insulated conductor heater 562 may have one or more conductors575. For example, a single insulated conductor heater may have threeconductors within electrical insulation that are surrounded by a sheath.FIG. 16 depicts an insulated conductor heater 562 having a singleconductor 575. The conductor may be made of metal. The material used toform a conductor may be, but is not limited to, nichrome, nickel, and anumber of alloys made from copper and nickel in increasing nickelconcentrations from pure copper to Alloy 30, Alloy 60, Alloy 180 andMonel. Alloys of copper and nickel may advantageously have betterelectrical resistance properties than substantially pure nickel orcopper.

[0366] In an embodiment, the conductor may be chosen to have a diameterand a resistivity at operating temperatures such that its resistance, asderived from Ohm's law, makes it electrically and structurally stablefor the chosen power dissipation per meter, the length of the heater,and/or the maximum voltage allowed to pass through the conductor. In analternate embodiment, the conductor may be designed, using Maxwell'sequations, to make use of skin effect heating in and/or on theconductor.

[0367] The conductor may be made of different material along a length ofthe insulated conductor heater. For example, a first section of theconductor may be made of a material that has a significantly lowerresistance than a second section of the conductor. The first section maybe placed adjacent to a formation layer that does not need to be heatedto as high a temperature as a second formation layer that is adjacent tothe second section. The resistivity of various sections of conductor maybe adjusted by having a variable diameter and/or by having conductorsections made of different materials.

[0368] A diameter of a conductor 575 may typically be between about 1.3mm to about 10.2 mm. Smaller or larger diameters may also be used tohave conductors with desired resistivity characteristics. In anembodiment of an insulated conductor heater, the conductor is made ofAlloy 60 that has a diameter of about 5.8 mm.

[0369] As illustrated in FIG. 16, an electrical insulator 576 of aninsulated conductor heater 562 may be made of a variety of materials.Pressure may be used to place electrical insulator powder between aconductor 575 and a sheath 577. Low flow characteristics and otherproperties of the powder and/or the sheaths and conductors may inhibitthe powder from flowing out of the sheaths. Commonly used powders mayinclude, but are not limited to, MgO, Al₂O₃, Zirconia, BeO, differentchemical variations of Spinels, and combinations thereof. MgO mayprovide good thermal conductivity and electrical insulation properties.The desired electrical insulation properties include low leakage currentand high dielectric strength. A low leakage current decreases thepossibility of thermal breakdown and the high dielectric strengthdecreases the possibility of arcing across the insulator. Thermalbreakdown can occur if the leakage current causes a progressive rise inthe temperature of the insulator leading also to arcing across theinsulator. An amount of impurities 578 in the electrical insulatorpowder may be tailored to provide required dielectric strength and a lowlevel of leakage current. The impurities 578 added may be, but are notlimited to, CaO, Fe₂O₃, Al₂O₃, and other metal oxides. Low porosity ofthe electrical insulation tends to reduce leakage current and increasedielectric strength. Low porosity may be achieved by increased packingof the MgO powder during fabrication or by filling of the pore space inthe MgO powder with other granular materials, for example, Al₂O₃.

[0370] The impurities 578 added to the electrical insulator powder mayhave particle sizes that are smaller than the particle sizes of thepowdered electrical insulator. The small particles may occupy pore spacebetween the larger particles of the electrical insulator so that theporosity of the electrical insulator is reduced. Examples of powderedelectrical insulators that may be used to form electrical insulation 576are “H” mix manufactured by Idaho Laboratories Corporation (Idaho Falls,Id.), or Standard MgO used by Pyrotenax Cable Company (Trenton, Ontario)for high temperature applications. In addition, other powderedelectrical insulators may be used.

[0371] A sheath 577 of an insulated conductor heater 562 may be an outermetallic layer. The sheath 577 may be in contact with hot formationfluids. The sheath 577 may need to be made of a material having a highresistance to corrosion at elevated temperatures. Alloys that may beused in a desired operating temperature range of the sheath include, butare not limited to, 304 stainless steel, 310 stainless steel, Incoloy800, and Inconel 600. The thickness of the sheath has to be sufficientto last for three to ten years in a hot and corrosive environment. Athickness of the sheath may generally vary between about 1 mm and about2.5 mm. For example, a 1.3 mm thick 310 stainless steel outer layerprovides a sheath 577 that is able to provide good chemical resistanceto sulfidation corrosion in a heated zone of a formation for a period ofover 3 years. Larger or smaller sheath thicknesses may be used to meetspecific application requirements.

[0372] An insulated conductor heater may be tested after fabrication.The insulated conductor heater may be required to withstand 2-3 times anoperating voltage at a selected operating temperature. Also, selectedsamples of produced insulated conductor heaters may be required towithstand 1000 VAC at 760° C. for one month.

[0373] As illustrated in FIG. 17a, a short flexible transition conductor571 may be connected to a lead-in conductor 572 using a connection 569made during heater installation in the field. The transition conductor571 may, for example, be a flexible, low resistivity, stranded coppercable that is surrounded by rubber or polymer insulation. A transitionconductor 571 may typically be between about 1.5 m and about 3 m,although longer or shorter transition conductors may be used toaccommodate particular needs. Temperature resistant cable may be used astransition conductor 571. The transition conductor 571 may also beconnected to a short length of an insulated conductor heater that isless resistive than a primary heating section of the insulated conductorheater. The less resistive portion of the insulated conductor heater maybe referred to as a “cold pin” 568.

[0374] A cold pin 568 may be designed to dissipate about one tenth toabout one fifth of the power per unit length as is dissipated in a unitlength of the primary heating section. Cold pins may typically bebetween about 1.5 m to about 15 m, although shorter or longer lengthsmay be used to accommodate specific application needs. In an embodiment,the conductor of a cold pin section is copper with a diameter of about6.9 mm and a length of 9.1 m. The electrical insulation is the same typeof insulation used in the primary heating section. A sheath of the coldpin may be made of Inconel 600. Chloride corrosion cracking in the coldpin region may occur, so a chloride corrosion resistant metal such asInconel 600 may be used as the sheath.

[0375] As illustrated in FIG. 17a, a small, epoxy filled canister 573may be used to create a connection between a transition conductor 571and a cold pin 568. Cold pins 568 may be connected to the primaryheating sections of insulated conductor 562 heaters by “splices” 567.The length of the cold pin 568 may be sufficient to significantly reducea temperature of the insulated conductor heater 562. The heater sectionof the insulated conductor heater 562 may operate from about 530° C. toabout 760° C., the splice 567 may be at a temperature from about 260° C.to about 370° C., and the temperature at the lead-in cable connection tothe cold pin may be from about 40° C. to about 90° C. In addition to acold pin at a top end of the insulated conductor heater, a cold pin mayalso be placed at a bottom end of the insulated conductor heater. Thecold pin at the bottom end may in many instances make a bottomtermination easier to manufacture.

[0376] Splice material may have to withstand a temperature equal to halfof a target zone operating temperature. Density of electrical insulationin the splice should in many instances be high enough to withstand therequired temperature and the operating voltage.

[0377] A splice 567 may be required to withstand 1000 VAC at 480° C.Splice material may be high temperature splices made by IdahoLaboratories Corporation or by Pyrotenax Cable Company. A splice may bean internal type of splice or an external splice. An internal splice istypically made without welds on the sheath of the insulated conductorheater. The lack of weld on the sheath may avoid potential weak spots(mechanical and/or electrical) on the insulated cable heater. Anexternal splice is a weld made to couple sheaths of two insulatedconductor heaters together. An external splice may need to be leaktested prior to insertion of the insulated cable heater into aformation. Laser welds or orbital TIG (tungsten inert gas) welds may beused to form external splices. An additional strain relief assembly maybe placed around an external splice to improve the splice's resistanceto bending and to protect the external splice against partial or totalparting.

[0378] An insulated conductor assembly may include heating sections,cold pins, splices, and termination canisters and flexible transitionconductors. The insulated conductor assembly may need to be examined andelectrically tested before installation of the assembly into an openingin a formation. The assembly may need to be examined for competent weldsand to make sure that there are no holes in the sheath anywhere alongthe whole heater (including the heated section, the cold-pins, thesplices and the termination cans). Periodic X-ray spot checking of thecommercial product may need to be made. The whole cable may be immersedin water prior to electrical testing. Electrical testing of the assemblymay need to show more than 2000 megaohms at 500 VAC at room temperatureafter water immersion. In addition, the assembly may need to beconnected to 1000 VAC and show less than about 10 microamps per meter ofresistive leakage current at room temperature. Also, a check on leakagecurrent at about 760° C. may need to show less than about 0.4 milliampsper meter.

[0379] There are a number of companies that manufacture insulatedconductor heaters. Such manufacturers include, but are not limited to,MI Cable Technologies (Calgary, Alberta), Pyrotenax Cable Company(Trenton, Ontario), Idaho Laboratories Corporation (Idaho Falls, Id.),and Watlow (St. Louis, Mo.). As an example, an insulated conductorheater may be ordered from Idaho Laboratories as cable model355-A90-310-“H”30′/750′/30′ with Inconel 600 sheath for the cold-pins,three phase Y configuration and bottom jointed conductors. The requiredspecification for the heater should also include 1000 VAC, 1400° F.quality cable in addition to the preferred mode specifications describedabove. The designator 355 specifies the cable OD (0.355′), A90 specifiesthe conductor material, 310 specifies the heated zone sheath alloy(SS310), “H” specifies the MgO mix, 30′/750′/30′ specifies about a 230 mheated zone with cold-pins top and bottom having about 9 m lengths. Asimilar part number with the same specification using high temperatureStandard purity MgO cable may be ordered from Pyrotenax Cable Company.

[0380] One or more insulated conductor heaters may be placed within anopening in a formation to form a heat source or heat sources. Electricalcurrent may be passed through each insulated conductor heater in theopening to heat the formation. Alternately, electrical current may bepassed through selected insulated conductor heaters in an opening. Theunused conductors may be backup heaters. Insulated conductor heaters maybe electrically coupled to a power source in any convenient manner. Eachend of an insulated conductor heater may be coupled to lead-in cablesthat pass through a wellhead. Such a configuration typically has a 180°bend (a “hairpin” bend) or turn located near a bottom of the heatsource. An insulated conductor heater that includes a 180° bend or turnmay not require a bottom termination, but the 180° bend or turn may bean electrical and/or structural weakness in the heater. Insulatedconductor heaters may be electrically coupled together in series, inparallel, or in series and parallel combinations. In some embodiments ofheat sources, electrical current may pass into the conductor of aninsulated conductor heater and may returned through the sheath of theinsulated conductor heater by connecting the conductor 575 to the sheath577 at the bottom of the heat source.

[0381] In an embodiment of a heat source depicted in FIG. 17, threeinsulated conductor heaters 562 are electrically coupled in a 3-phase Yconfiguration to a power supply. The power supply may provide a 60 cycleAC current to the electrical conductors. No bottom connection may berequired for the insulated conductor heaters. Alternately, all threeconductors of the three phase circuit may be connected together near thebottom of a heat source opening. The connection may be made directly atends of heating sections of the insulated conductor heaters or at endsof cold pins coupled to the heating sections at the bottom of theinsulated conductor heaters. The bottom connections may be made withinsulator filled and sealed canisters or with epoxy filled canisters.The insulator may be the same composition as the insulator used as theelectrical insulation.

[0382] The three insulated conductor heaters depicted in FIG. 17 may becoupled to support member 564 using centralizers 566. Alternatively, thethree insulated conductor heaters may be strapped directly to thesupport tube using metal straps. Centralizers 566 may be configured tomaintain a location of insulated conductor heaters 562 on support member564. Centralizers 566 may be made of, for example, metal, ceramic or acombination thereof. The metal may be stainless steel or any other typeof metal able to withstand a corrosive and hot environment. In someembodiments, centralizers 566 may be simple bowed metal strips welded tothe support member at distances less than about 6 meters. A ceramic usedin centralizer 566 may be, but is not limited to, Al₂O₃, MgO or otherinsulator. Centralizers 566 may be configured to maintain a location ofinsulated conductor heaters 562 on support member 564 such that movementof insulated conductor heaters may be substantially inhibited atoperating temperatures of the insulated conductor heaters. Insulatedconductor heaters 562 may also be somewhat flexible to withstandexpansion of support member 564 during heating. Centralizers 566 mayalso be configured as described in any of the embodiments herein.

[0383] Support member 564, insulated conductor heater 562, andcentralizers 566 may be placed in opening 514 in coal formation 516.Insulated conductor heaters 562 may be coupled to bottom conductorjunction 570 using cold pin transition conductor 568. Bottom conductorjunction 570 may electrically couple each insulated conductor heater 562to each other. Bottom conductor junction 570 may include materials thatare electrically conducting and do not melt at temperatures found inopening 514. Cold pin transition conductor 568 may be an insulatedconductor heater having lower electrical resistance than insulatedconductor heater 562. As illustrated in FIG. 17a, cold pin 568 may becoupled to transition conductor 571 and insulated conductor heater 562.Cold pin transition conductor 568 may provide a temperature transitionbetween transition conductor 571 and insulated conductor heater 562.

[0384] Lead-in conductor 572 may be coupled to wellhead 590 to provideelectrical power to insulated conductor heater 562. Wellhead 590 may beconfigured as shown in FIG. 18 and as described in any of theembodiments herein. Lead-in conductor 572 may be made of a relativelylow electrical resistance conductor such that relatively little orsubstantially no heat may be generated from electrical current passingthrough lead-in conductor 572. For example, the lead-in conductor mayinclude, but may not be limited to, a rubber insulated stranded copperwire, but the lead-in conductor may also be a mineral-insulatedconductor with a copper core. Lead-in conductor 572 may couple to awellhead 590 at surface 550 through a sealing flange located betweenoverburden 540 and surface 550. The sealing flange 590 c may beconfigured as shown in FIG. 18 and as described in any of theembodiments herein. The sealing flange may substantially inhibit fluidfrom escaping from opening 514 to surface 550.

[0385] Packing material 542 (see FIG. 17) may optionally be placedbetween overburden casing 541 and opening 514. Overburden casing 541 mayinclude any materials configured to substantially contain cement 544. Inan embodiment of a heater source, overburden casing is a 7.6 cm (3 inch)diameter carbon steel, schedule 40 pipe. Packing material 542 may beconfigured to inhibit fluid from flowing from opening 514 to surface550. Overburden casing 541 may be placed in cement 544 in overburden 540of formation 516. Cement 544 may include, for example, Class G or ClassH Portland cement mixed with silica flour for improved high temperatureperformance, slag or silica flour, and/or a mixture thereof (e.g., about1.58 grams per cubic centimeter slag/silica flour). In selected heatsource embodiments, cement 544 extends radially a width of from about 5cm to about 25 cm. In some embodiments cement 544 may extend radially awidth of about 10 cm to about 15 cm. In some other embodiments, cement544 may be designed to inhibit heat transfer from conductor 564 intoformation 540 within the overburden.

[0386] In certain embodiments one or more conduits may be provided tosupply additional components (e.g., nitrogen, carbon dioxide, reducingagents such as gas containing hydrogen, etc.) to formation openings, tobleed off fluids, and/or to control pressure. Formation pressures tendto be highest near heating sources and thus it is often beneficial tohave pressure control equipment proximate the heating source. In someembodiments adding a reducing agent proximate the heating source assistsin providing a more favorable pyrolysis environment (e.g., a higherhydrogen partial pressure). Since permeability and porosity tend toincrease more quickly proximate the heating source, it is often optimalto add a reducing agent proximate the heating source so that thereducing agent can more easily move into the formation.

[0387] In FIG. 17, for example, conduit 5000 may be provided to add gasfrom gas source 5003, through valve 5001, and into opening 514 (anopening 5004 is provided in packing material 542 to allow gas to passinto opening 514). Conduit 5000 and valve 5002 may also be used atdifferent times to bleed off pressure and/or control pressure proximateto opening 514. In FIG. 19, for example, conduit 5010 may be provided toadd gas from gas source 5013, through valve 5011, and into opening 514(an opening is provided in cement 544 to allow gas to pass into opening514). Conduit 5010 and valve 5012 may also be used at different times tobleed off pressure and/or control pressure proximate to opening 514. Itis to be understood that any of the heating sources described herein mayalso be equipped with conduits to supply additional components, bleedoff fluids, and/or to control pressure.

[0388] Support member 564 and lead-in conductor 572 may be coupled towellhead 590 at surface 550 of formation 516. Surface conductor 545 mayenclose cement 544 and may couple to wellhead 590. Embodiments of heatersource surface conductor 545 may have a diameter of about 10.16 cm toabout 30.48 cm or, for example, a diameter of about 22 cm. Embodimentsof surface casings may extend to depths of approximately 3 m toapproximately 515 m into an opening in the formation. Alternatively, thesurface casing may extend to a depth of approximately 9 m into theopening. Electrical current may be supplied from a power source toinsulated conductor heater 562 to generate heat due to the electricalresistance of conductor 575 as illustrated in FIG. 16. As an example, avoltage of about 330 volts and a current of about 266 amps are suppliedto insulated conductors 562 to generate a heat of about 1150 watts/meterin insulated conductor heater 562. Heat generated from the threeinsulated conductor heaters 562 may transfer (e.g., by radiation) withinopening 514 to heat at least a portion of the formation 516.

[0389] An appropriate configuration of an insulated conductor heater maybe determined by optimizing a material cost of the heater based on alength of heater, a power required per meter of conductor, and a desiredoperating voltage. In addition, an operating current and voltage may bechosen to optimize the cost of input electrical energy in conjunctionwith a material cost of the insulated conductor heaters. For example, asinput electrical energy increases, the cost of materials needed towithstand the higher voltage may also increase. The insulated conductorheaters may be configured to generate a radiant heat of approximately650 watts/meter of conductor to approximately 1650 watts/meter ofconductor. The insulated conductor heater may operate at a temperaturebetween approximately 530° C. and approximately 760° C. within aformation.

[0390] Heat generated by an insulated conductor heater may heat at leasta portion of a coal formation. In some embodiments heat may betransferred to the formation substantially by radiation of the generatedheat to the formation. Some heat may be transferred by conduction orconvection of heat due to gases present in the opening. The opening maybe an uncased opening. An uncased opening eliminates cost associatedwith thermally cementing the heater to the formation, costs associatedwith a casing, and/or costs of packing a heater within an opening. Inaddition, the heat transfer by radiation is generally more efficientthan by conduction so the heaters will operate at lower temperatures inan open wellbore. The conductive heat transfer may be enhanced by theaddition of a gas in the opening at pressures up to about 27 barabsolute. The gas may include, but may not be limited to, carbon dioxideand/or helium. Still another advantage is that the heating assembly willbe free to undergo thermal expansion. Yet another advantage is that theheaters may be replaceable.

[0391] The insulated conductor heater, as described in any of theembodiments herein, may be installed in opening 514 by any method knownin the art. In an embodiment, more than one spooling assembly may beused to install both the electric heater and a support membersimultaneously. U.S. Pat. No. 4,572,299 issued to Van Egmond et al.,which is incorporated by reference as if fully set forth herein,describes spooling an electric heater into a well. Alternatively, thesupport member may be installed using a coiled tubing unit including anyunit known in the art. The heaters may be un-spooled and connected tothe support as the support is inserted into the well. The electricheater and the support member may be un-spooled from the spoolingassemblies. Spacers may be coupled to the support member and the heateralong a length of the support member. Additional spooling assemblies maybe used for additional electric heater elements.

[0392] In an embodiment, the support member may be installed usingstandard oil field operations and welding different sections of support.Welding may be done by using orbital welding. For example, a firstsection of the support member may be disposed into the well. A secondsection (e.g., of substantially similar length) may be coupled to thefirst section in the well. The second section may be coupled by weldingthe second section to the first section. An orbital welder disposed atthe wellhead may be configured to weld the second section to the firstsection. This process may be repeated with subsequent sections coupledto previous sections until a support of desired length is within thewell.

[0393]FIG. 18 illustrates a cross-sectional view of one embodiment of awellhead coupled, e.g., to overburden casing 541. Flange 590 c may becoupled to, or may be a part of, wellhead 590. Flange 590 c may be, forexample, carbon steel, stainless steel or any other commerciallyavailable suitable sealing material. Flange 590 c may be sealed witho-ring 590 f, or any other sealing mechanism. Thermocouples 590 g may beprovided into wellhead 590 through flange 590 c. Thermocouples 590 g maymeasure a temperature on or proximate to support member 564 within theheated portion of the well. Support member 564 may be coupled to flange590 c. Support member 564 may be configured to support one or moreinsulated conductor heaters as described herein. Support member 564 maybe sealed in flange 590 c by welds 590 h. Alternately, support member564 may be sealed by any method known in the art.

[0394] Power conductor 590 a may be coupled to a lead-in cable and/or aninsulated conductor heater. Power conductor 590 a may be configured toprovide electrical energy to the insulated conductor heater. Powerconductor 590 a may be sealed in sealing flange 590 d. Sealing flange590 d may be sealed by compression seals or o-rings 590 e. Powerconductor 590 a may be coupled to support member 564 with band 590 i.Band 590 i may include a rigid and corrosion resistant material such asstainless steel. Wellhead 590 may be sealed with weld 590 h such thatfluid may be substantially inhibited from escaping the formation throughwellhead 590. Lift bolt 590 j may be configured to lift wellhead 590 andsupport member 564. Wellhead 590 may also include a pressure controlvalve. Compression fittings 590 k may serve to seal power cable 590 aand compression fittings 590 l may serve to seal thermocouple 590 g.These seals inhibit fluids from escaping the formation. The pressurecontrol valve may be configured to control a pressure within an openingin which support member 564 may be disposed.

[0395] In an embodiment, a control system may be configured to controlelectrical power supplied to an insulated conductor heater. Powersupplied to the insulated conductor heater may be controlled with anyappropriate type of controller. For alternating current, the controllermay, for example, be a tapped transformer. Alternatively, the controllermay be a zero crossover electrical heater firing SCR (silicon controlledrectifier) controller. Zero crossover electrical heater firing controlmay be achieved by allowing full supply voltage to the insulatedconductor heater to pass through the insulated conductor heater for aspecific number of cycles, starting at the “crossover,” where aninstantaneous voltage may be zero, continuing for a specific number ofcomplete cycles, and discontinuing when the instantaneous voltage againmay cross zero. A specific number of cycles may be blocked, allowingcontrol of the heat output by the insulated conductor heater. Forexample, the control system may be arranged to block fifteen and/ortwenty cycles out of each sixty cycles that may be supplied by astandard 60 Hz alternating current power supply. Zero crossover firingcontrol may be advantageously used with materials having a lowtemperature coefficient materials. Zero crossover firing control maysubstantially inhibit current spikes from occurring in an insulatedconductor heater.

[0396]FIG. 19 illustrates an embodiment of a conductor-in-conduit heaterconfigured to heat a section of a coal formation. Conductor 580 may bedisposed in conduit 582. Conductor 580 may be a rod or conduit ofelectrically conductive material. A conductor 580 may have a lowresistance section 584 at both the top and the bottom of the conductor580 in order to generate less heating in these sections 584. Thesubstantially low resistance section 584 may be due to a greatercross-sectional area of conductor 580 in that section. For example,conductor 580 may be a 304 or 310 stainless steel rod with a diameter ofapproximately 2.8 cm. The diameter and wall thickness of conductor 580may vary, however, depending on, for example, a desired heating rate ofthe coal formation. Conduit 582 may include an electrically conductivematerial. For example, conduit 582 may be a 304 or 310 stainless steelpipe having a diameter of approximately 7.6 cm and a thickness ofapproximately schedule 40. Conduit 582 may be disposed in opening 514 information 516. Opening 514 may have a diameter of at least approximately5 cm. The diameter of the opening may vary, however, depending on, forexample, a desired heating rate in the formation and/or a diameter ofconduit 582. For example, a diameter of the opening may be from about 10cm to about 13 cm. Larger diameter openings may also be used. Forexample, a larger opening may be used if more than one conductor is tobe placed within a conduit.

[0397] Conductor 580 may be centered in conduit 582 through centralizer581. Centralizer 581 may electrically isolate conductor 580 from conduit582. In addition, centralizer 581 may be configured to locate conductor580 within conduit 582. Centralizer 581 may be made of a ceramicmaterial or a combination of ceramic and metallic materials. More thanone centralizer 581 may be configured to substantially inhibitdeformation of conductor 580 in conduit 582 during use. More than onecentralizer 581 may be spaced at intervals between approximately 0.5 mand approximately 3 m along conductor 580. Centralizer 581 may be madeof ceramic, 304 stainless steel, 310 stainless steel, or other types ofmetal. Centralizer 581 may be configured as shown in FIG. 22 and/orFIGS. 23a and 23 b.

[0398] As depicted in FIG. 20, sliding connector 583 may couple an endof conductor 580 disposed proximate a lowermost surface of conduit 582.Sliding connector 583 allows for differential thermal expansion betweenconductor 580 and conduit 582. Sliding connector 583 is attached to aconductor 580 located at the bottom of the well at a low resistancesection 584 which may have a greater cross-sectional area. The lowerresistance of section 584 allows the sliding connector to operate attemperatures no greater than about 90° C. In this manner, corrosion ofthe sliding connector components is minimized and therefore contactresistance between sliding connector 583 and conduit 582 is alsominimized. Sliding connector 583 may be configured as shown in FIG. 20and as described in any of the embodiments herein. The substantially lowresistance section 584 of the conductor 580 may couple conductor 580 towellhead 690 as depicted in FIG. 19. Wellhead 690 may be configured asshown in FIG. 21 and as described in any of the embodiments herein.Electrical current may be applied to conductor 580 from power cable 585through a low resistance section 584 of the conductor 580. Electricalcurrent may pass from conductor 580 through sliding connector 583 toconduit 582. Conduit 582 may be electrically insulated from overburdencasing 541 and from wellhead 690 to return electrical current to powercable 585. Heat may be generated in conductor 580 and conduit 582. Thegenerated heat may radiate within conduit 582 and opening 514 to heat atleast a portion of formation 516. As an example, a voltage of about 330volts and a current of about 795 amps may be supplied to conductor 580and conduit 582 in a 229 m (750 ft) heated section to generate about1150 watts/meter of conductor 580 and conduit 582.

[0399] Overburden conduit 541 may be disposed in overburden 540 offormation 516. Overburden conduit 541 may in some embodiments besurrounded by materials that may substantially inhibit heating ofoverburden 540. A substantially low resistance section 584 of aconductor 580 may be placed in overburden conduit 541. The substantiallylow resistance section 584 of conductor 580 may be made of, for example,carbon steel. The substantially low resistance section 584 may have adiameter between about 2 cm to about 5 cm or, for example, a diameter ofabout 4 cm. A substantially low resistance section 584 of conductor 580may be centralized within overburden conduit 541 using centralizers 581.Centralizers 581 may be spaced at intervals of approximately 6 m toapproximately 12 m or, for example, approximately 9 m alongsubstantially low resistance section 584 of conductor 580. Asubstantially low resistance section 584 of conductor 580 may be coupledto conductor 580 using any method known in the art such as arc welding.A substantially low resistance section 584 may be configured to generatelittle and/or substantially no heat in overburden conduit 541. Packingmaterial 542 may be placed between overburden casing 541 and opening514. Packing material 542 may be configured to substantially inhibitfluid from flowing from opening 514 to surface 550 or to inhibit mostheat carrying fluids from flowing from opening 514 to surface 550.

[0400] Overburden conduit may include, for example, a conduit of carbonsteel having a diameter of about 7.6 cm and a thickness of aboutschedule 40 pipe. Cement 544 may include, for example, slag or silicaflour, or a mixture thereof (e.g., about 1.58 grams per cubic centimeterslag/silica flour). Cement 544 may extend radially a width of about 5 cmto about 25 cm. Cement 544 may also be made of material designed toinhibit flow of heat into formation 516.

[0401] Surface conductor 545 and overburden casing 541 may enclosecement 544 and may couple to wellhead 690. Surface conductor 545 mayhave a diameter of about 10 cm to about 30 cm and more preferably adiameter of about 22 cm. Electrically insulating sealing flanges may beconfigured to mechanically couple substantially low resistance section584 of conductor 580 to wellhead 690 and to electrically couple lowerresistance section 584 to power cable 585. The electrically insulatingsealing flanges may be configured to couple lead-in conductor 585 towellhead 690. For example, lead-in conductor 585 may include a coppercable, wire, or other elongated member. Lead-in conductor 585 mayinclude, however, any material having a substantially low resistance.The lead-in conductor may be clamped to the bottom of the lowresistivity conductor to make electrical contact.

[0402] In an embodiment, heat may be generated in or by conduit 582. Inthis manner, about 10% to about 30%, or, for example, about 20%, of thetotal heat generated by the heater may be generated in or by conduit582. Both conductor 580 and conduit 582 may be made of stainless steel.Dimensions of conductor 580 and conduit 582 may be chosen such that theconductor will dissipate heat in a range from approximately 650 wattsper meter to 1650 watts per meter. A temperature in conduit 582 may beapproximately 480° C. to approximately 815° C. and a temperature inconductor 580 may be approximately 500° C. to 840° C. Substantiallyuniform heating of a coal formation may be provided along a length ofconduit 582 greater than about 300 m or, maybe, greater than about 600m. A length of conduit 582 may vary, however, depending on, for example,a type of coal formation, a depth of an opening in the formation, and/ora length of the formation desired for treating.

[0403] The generated heat may be configured to heat at least a portionof a coal formation. Heating of at least the portion may occursubstantially by radiation of the generated heat within an opening inthe formation and to a lesser extent by gas conduction. In this manner,a cost associated with filling the opening with a filling material toprovide conductive heat transfer between the insulated conductor and theformation may be eliminated. In addition, heat transfer by radiation isgenerally more efficient than by conduction so the heaters willgenerally operate at lower temperatures in an open wellbore. Stillanother advantage is that the heating assembly will be free to undergothermal expansion. Yet another advantage is that the heater may bereplaceable.

[0404] The conductor-in-conduit heater, as described in any of theembodiments herein, may be installed in opening 514. In an embodiment,the conductor-in-conduit heater may be installed into a well bysections. For example, a first section of the conductor-in-conduitheater may be disposed into the well. The section may be about 12 m inlength. A second section (e.g., of substantially similar length) may becoupled to the first section in the well. The second section may becoupled by welding the second section to the first section and/or withthreads disposed on the first and second section. An orbital welderdisposed at the wellhead may be configured to weld the second section tothe first section. This process may be repeated with subsequent sectionscoupled to previous sections until a heater of desired length may bedisposed in the well. In some embodiments, three sections may be coupledprior to being disposed in the well. The three sections may be coupledby welding. The three sections may have a length of about 12.2 m each.The resulting 37 m section may be lifted vertically by a crane at thewellhead. The three sections may be coupled to three additional sectionsin the well as described herein. Welding the three sections prior tobeing disposed in the well may reduce a number of leaks and/or faultywelds and may decrease a time required for installation of the heater.

[0405] In an alternate embodiment, the conductor-in-conduit heater maybe spooled onto a spooling assembly. The spooling assembly may bemounted on a transportable structure. The transportable structure may betransported to a well location. The conductor-in-conduit heater may beun-spooled from the spooling assembly into the well.

[0406]FIG. 20 illustrates an embodiment of a sliding connector. Slidingconnector 583 may include scraper 593 that may abut an inner surface ofconduit 582 at point 595. Scraper 593 may include any metal orelectrically conducting material (e.g., steel or stainless steel).Centralizer 591 may couple to conductor 580. In some embodiments,conductor 580 may have a substantially low resistance section 584, dueto an increased thickness, substantially around a location of slidingconnector 583. Centralizer 591 may include any electrically conductingmaterial (e.g., a metal or metal alloy). Centralizer 591 may be coupledto scraper 593 through spring bow 592. Spring bow 592 may include anymetal or electrically conducting material (e.g., copper-berylliumalloy). Centralizer 591, spring bow 592, and/or scraper 593 may becoupled through any welding method known in the art. Sliding connector583 may electrically couple the substantially low resistance section 584of conductor 580 to conduit 582 through centralizer 591, spring bow 592,and/or scraper 593. During heating of conductor 580, conductor 580 mayexpand at a substantially different rate than conduit 582. For example,point 594 on conductor 580 may move relative to point 595 on conduit 582during heating of conductor 580. Scraper 593 may maintain electricalcontact with conduit 582 by sliding along surface of conduit 582.Several sliding connectors may be used for redundancy and to reduce thecurrent at each scraper. In addition, a thickness of conduit 582 may beincreased for a length substantially adjacent to sliding connector 583to substantially reduce heat generated in that portion of the conduit582. The length of conduit 582 with increased thickness may be, forexample, approximately 6 m.

[0407]FIG. 21 illustrates another embodiment of a wellhead. Wellhead 690may be coupled to electrical junction box 690 a by flange 690 n or anyother suitable mechanical device. Electrical junction box 690 a may beconfigured to control power (current and voltage) supplied to anelectric heater. The electric heater may be a conductor-in-conduitheater as described herein. Flange 690 n may include, for example,stainless steel or any other suitable sealing material. Conductor 690 bmay be disposed in flange 690 n and may electrically couple overburdencasing 541 to electrical junction box 690 a. Conductor 690 b may includeany metal or electrically conductive material (e.g., copper).Compression seal 690 c may seal conductor 690 b at an inner surface ofelectrical junction box 690 a.

[0408] Flange 690 n may be sealed with metal o-ring 690 d. Conduit 690f, which may be, e.g., a pipe, may couple flange 690 n to flange 690 m.Flange 690 m may couple to overburden casing 541. Flange 690 m may besealed with o-ring 690 g (e.g., metal o-ring or steel o-ring). Thesubstantially low resistance section 584 of the conductor (e.g.,conductor 580) may couple to electrical junction box 690 a. Thesubstantially low resistance section 584 may be passed through flange690 n and may be sealed in flange 690 n with o-ring assembly 690 p.Assemblies 690 p are designed to insulate the substantially lowresistance section 584 of conductor 580 from flange 690 n and flange 690m. O-ring assembly 690 c may be designed to electrically insulateconductor 690 b from flange 690 m and junction box 690 a. Centralizer581 may couple to low resistance section 584. Electrically insulatingcentralizer 581 may have characteristics as described in any of theembodiments herein. Thermocouples 690 i may be coupled to thermocoupleflange 690 q with connectors 690 h and wire 690 j. Thermocouples 690 imay be enclosed in an electrically insulated sheath (e.g., a metalsheath). Thermocouples 690 i may be sealed in thermocouple flange 690 qwith compression seals 690 k. Thermocouples 690 i may be used to monitortemperatures in the heated portion downhole.

[0409]FIG. 22 illustrates a perspective view of an embodiment of acentralizer in, e.g., conduit 582. Electrical insulator 581 a may bedisposed on conductor 580. Insulator 581 a may be made of, for example,aluminum oxide or any other electrically insulating material that may beconfigured for use at high temperatures. A location of insulator 581 aon the conductor 580 may be maintained by disc 581 d. Disc 581 d may bewelded to conductor 580. Spring bow 581 c may be coupled to insulator581 a by disc 581 b. Spring bow 581 c and disc 581 b may be made ofmetals such as 310 stainless steel and any other thermally conductingmaterial that may be configured for use at high temperatures.Centralizer 581 may be arranged as a single cylindrical member disposedon conductor 580. Centralizer 581 may be arranged as twohalf-cylindrical members disposed on conductor 580. The twohalf-cylindrical members may be coupled to conductor 580 by band 581 e.Band 581 e may be made of any material configured for use at hightemperatures (e.g., steel).

[0410]FIG. 23a illustrates a cross-sectional view of an embodiment of acentralizer 581 e disposed on conductor 580. FIG. 23b illustrates aperspective view of the embodiment shown in FIG. 23a. Centralizer 581 emay be made of any suitable electrically insulating material that maysubstantially withstand high voltage at high temperatures. Examples ofsuch materials may be aluminum oxide and/or Macor. Discs 581 d maymaintain positions of centralizer 581 e relative to conductor 580. Discs581 d may be metal discs welded to conductor 580. Discs 581 d may betack-welded to conductor 580. Centralizer 581 e may substantiallyelectrically insulate conductor 580 from conduit 582.

[0411] In an embodiment, a conduit may be pressurized with a fluid tobalance a pressure in the conduit with a pressure in an opening. In thismanner, deformation of the conduit may be substantially inhibited. Athermally conductive fluid may be configured to pressurize the conduit.The thermally conductive fluid may increase heat transfer within theconduit. The thermally conductive fluid may include a gas such ashelium, nitrogen, air, or mixtures thereof. A pressurized fluid may alsobe configured to pressurize the conduit such that the pressurized fluidmay inhibit arcing between the conductor and the conduit. If air and/orair mixtures are used to pressurize the conduit, the air and/or airmixtures may react with materials of the conductor and the conduit toform an oxide on a surface of the conductor and the conduit such thatthe conductor and the conduit are at least somewhat more resistant tocorrosion.

[0412] An emissivity of a conductor and/or a conduit may be increased.For example, a surface of the conductor and/or the conduit may beroughened to increase the emissivity. Blackening the surface of theconductor and/or the conduit may also increase the emissivity.Alternatively, oxidation of the conductor and/or the conduit prior toinstallation may be configured to increase the emissivity. The conductorand/or the conduit may also be oxidized by heating the conductor and/orthe conduit in the presence of an oxidizing fluid in the conduit and/orin an opening in a coal formation. Another alternative for increasingthe emissivity may be to anodize the conductor and/or the conduit suchthat the surface may be roughened and/or blackened.

[0413] In another embodiment, a perforated tube may be placed in theopening formed in the coal formation proximate to and external the firstconduit. The perforated tube may be configured to remove fluids formedin the opening. In this manner, a pressure may be maintained in theopening such that deformation of the first conduit may be substantiallyinhibited and the pressure in the formation near the heaters may bereduced. The perforated tube may also be used to increase or decreasepressure in the formation by addition or removal of a fluid or fluidsfrom the formation. This may allow control of the pressure in theformation and control of quality of produced hydrocarbons. Perforatedtubes may be used for pressure control in all described embodiments ofheat sources using an open hole configuration. The perforated tube mayalso be configured to inject gases to upgrade hydrocarbon properties insitu; for example, hydrogen gas may be injected under elevated pressure.

[0414]FIG. 24 illustrates an alternative embodiment of aconductor-in-conduit heater configured to heat a section of a coalformation. Second conductor 586 may be disposed in conduit 582 inaddition to conductor 580. Conductor 580 may be configured as describedherein. Second conductor 586 may be coupled to conductor 580 usingconnector 587 located near a lowermost surface of conduit 582. Secondconductor 586 may be configured as a return path for the electricalcurrent supplied to conductor 580. For example, second conductor 586 mayreturn electrical current to wellhead 690 through second substantiallylow resistance conductor 588 in overburden casing 541. Second conductor586 and conductor 580 may be configured of an elongated conductivematerial. Second conductor 586 and conductor 580 may be, for example, astainless steel rod having a diameter of approximately 2.4 cm. Connector587 may be flexible. Conduit 582 may be electrically isolated fromconductor 580 and second conductor 586 using centralizers 581.Overburden casing 541, cement 544, surface conductor 545, and packingmaterial 542 may be configured as described in the embodiment shown inFIG. 19. Advantages of this embodiment include the absence of a slidingcontactor, which may extend the life of the heater, and the isolation ofall applied power from formation 516.

[0415] In another embodiment, a second conductor may be disposed in asecond conduit, and a third conductor may be disposed in a thirdconduit. The second opening may be different from the opening for thefirst conduit. The third opening may be different from the opening forthe first conduit and the second opening. For example, each of thefirst, second, and third openings may be disposed in substantiallydifferent well locations of the formation and may have substantiallysimilar dimensions. The first, second, and third conductors may beconfigured as described herein. The first, second, and third conductorsmay be electrically coupled in a 3-phase Y electrical configuration. Theouter conduits may be connected together or may be connected to theground. The 3-phase Y electrical configuration may provide a safer, moreefficient method to heat a coal formation than using a single conductor.The first, second, and/or third conduits may be electrically isolatedfrom the first, second, and third conductors, respectively. Dimensionsof each conductor and each conduit may be configured such that eachconductor may generate heat of approximately 650 watts per meter ofconductor to approximately 1650 watts per meter of conductor. In anembodiment, a first conductor and a second conductor in a conduit may becoupled by a flexible connecting cable. The bottom of the first andsecond conductor may be enlarged to create low resistance sections, andthus generate less heat. In this manner, the flexible connector may bemade of, for example, stranded copper covered with rubber insulation.

[0416] In an embodiment, a first conductor and a second conductor may becoupled to at least one sliding connector within a conduit. The slidingconnector may be configured as described herein. For example, such asliding connector may be configured to generate less heat than the firstconductor or the second conductor. The conduit may be electricallyisolated from the first conductor, second conductor, and/or the slidingconnector. The sliding connector may be placed in a location within thefirst conduit where substantially less heating of the coal formation maybe required.

[0417] In an embodiment, a thickness of a section of a conduit may beincreased such that substantially less heat may be transferred (e.g.,radiated) along the section of increased thickness. The section withincreased thickness may preferably be formed along a length of theconduit where less heating of the coal formation may be required.

[0418] In an embodiment, the conductor may be formed of sections ofvarious metals that are welded together. The cross sectional area of thevarious metals may be selected to allow the resulting conductor to belong, to be creep resistant at high operating temperatures, and/or todissipate substantially the same amount of heat per unit length alongthe entire length of the conductor. For example a first section may bemade of a creep resistant metal (such as, but not limited to Inconel 617or HR120) and a second section of the conductor may be made of 304stainless steel. The creep resistant first section may help to supportthe second section. The cross sectional area of the first section may belarger than the cross sectional area of the second section. The largercross sectional area of the first section may allow for greater strengthof the first section. Higher resistivity properties of the first sectionmay allow the first section to dissipate the same amount of heat perunit length as the smaller cross sectional area second section.

[0419] In some embodiments, the cross sectional area and/or the metalused for a particular section may be chosen so that a particular sectionprovides greater (or lesser) heat dissipation per unit length than anadjacent section. More heat may be provided near an interface between ahydrocarbon layer and a non-hydrocarbon layer (e.g., the overburden andthe coal formation) to counteract end effects and allow for more uniformheat dissipation into the coal formation. A higher heat dissipation mayalso be located at a lower end of an elongated member to counteract endeffects and allow for more uniform heat dissipation.

[0420] In an embodiment, an elongated member may be disposed within anopening (e.g., an open wellbore) in a coal formation. The opening maypreferably be an uncased opening in the coal formation. The opening mayhave a diameter of at least approximately 5 cm or, for example,approximately 8 cm. The diameter of the opening may vary, however,depending on, for example, a desired heating rate in the formation. Theelongated member may be a length (e.g., a strip) of metal or any otherelongated piece of metal (e.g., a rod). The elongated member may includestainless steel. The elongated member, however, may also include anyconductive material configurable to generate heat to sufficiently heat aportion of the formation and to substantially withstand a correspondingtemperature within the opening, for example, it may be configured towithstand corrosion at the temperature within the opening.

[0421] An elongated member may be a bare metal heater. “Bare metal”refers to a metal that does not include a layer of electricalinsulation, such as mineral insulation, that is designed to provideelectrical insulation for the metal throughout an operating temperaturerange of the elongated member. Bare metal may encompass a metal thatincludes a corrosion inhibiter such as a naturally occurring oxidationlayer, an applied oxidation layer, and/or a film. Bare metal includesmetal with polymeric or other types of electrical insulation that cannotretain electrical insulating properties at typical operating temperatureof the elongated member. Such material may be placed on the metal andmay be thermally degraded during use of the heater.

[0422] An elongated member may have a length of about 650 meters. Longerlengths may be achieved using sections of high strength alloys, but suchelongated members may be expensive. In some embodiments, an elongatedmember may be supported by a plate in a wellhead. The elongated membermay include sections of different conductive materials that are weldedtogether end-to-end. A large amount of electrically conductive weldmaterial may be used to couple the separate sections together toincrease strength of the resulting member and to provide a path forelectricity to flow that will not result in arcing and/or corrosion atthe welded connections. The different conductive materials may includealloys with a high creep resistance. The sections of differentconductive materials may have varying diameters to ensure uniformheating along the elongated member. A first metal that has a highercreep resistance than a second metal typically has a higher resistivitythan the second metal. The difference in resistivities may allow asection of larger cross sectional area, more creep resistant first metalto dissipate the same amount of heat as a section of smaller crosssectional area second metal. The cross sectional areas of the twodifferent metals may be tailored to result in substantially the sameamount of heat dissipation in two welded together sections of themetals. The conductive materials may include, but are not limited to,617 Inconel, HR-120, 316 stainless steel, and 304 stainless steel. Forexample, an elongated member may have a 60 meter section of 617 Inconel,60 meter section of HR-120, and 150 meter section of 304 stainlesssteel. In addition, the elongated member may have a low resistancesection that may run from the wellhead through the overburden. This lowresistance section may decrease the heating within the formation fromthe wellhead through the overburden. The low resistance section may bethe result of, for example, choosing a substantially electricallyconductive material and/or increasing the cross-sectional area availablefor electrical conduction.

[0423] Alternately, a support member may extend through the overburden,and the bare metal elongated member or members may be coupled to aplate, a centralizer or other type of support member near an interfacebetween the overburden and the hydrocarbon formation. A low resistivitycable, such as a stranded copper cable, may extend along the supportmember and may be coupled to the elongated member or members. The coppercable may be coupled to a power source that supplies electricity to theelongated member or members.

[0424]FIG. 25 illustrates an embodiment of a plurality of elongatedmembers configured to heat a section of a coal formation. Two or more(e.g., four) elongated members 600 may be supported by support member604. Elongated members 600 may be coupled to support member 604 usinginsulated centralizers 602. Support member 604 may be a tube or conduit.Support member 604 may also be a perforated tube. Support member 604 maybe configured to provide a flow of an oxidizing fluid into opening 514.Support member 604 may have a diameter between about 1.2 cm to about 4cm and more preferably about 2.5 cm. Support member 604, elongatedmembers 600, and insulated centralizers 602 may be disposed in opening514 in formation 516. Insulated centralizers 602 may be configured tomaintain a location of elongated members 600 on support member 604 suchthat lateral movement of elongated members 600 may be substantiallyinhibited at temperatures high enough to deform support member 604 orelongated members 600. Insulated centralizers 602 may be a centralizeras described herein. Elongated members 600, in some embodiments, may bemetal strips of about 2.5 cm wide and about 0.3 cm thick stainlesssteel. Elongated members 600, however, may also include a pipe or a rodformed of a conductive material. Electrical current may be applied toelongated members 600 such that elongated members 600 may generate heatdue to electrical resistance.

[0425] Elongated members 600 may be configured to generate heat ofapproximately 650 watts per meter of elongated members 600 toapproximately 1650 watts per meter of elongated members 600. In thismanner, elongated members 600 may be at a temperature of approximately480° C. to approximately 815° C. Substantially uniform heating of a coalformation may be provided along a length of elongated members 600greater than about 305 m or, maybe, greater than about 610 m. A lengthof elongated members 600 may vary, however, depending on, for example, atype of coal formation, a depth of an opening in the formation, and/or alength of the formation desired for treating

[0426] Elongated members 600 may be electrically coupled in series.Electrical current may be supplied to elongated members 600 usinglead-in conductor 572. Lead-in conductor 572 may be further configuredas described herein. Lead-in conductor 572 may be coupled to wellhead690. Electrical current may be returned to wellhead 690 using lead-outconductor 606 coupled to elongated members 600. Lead-in conductor 572and lead-out conductor 606 may be coupled to wellhead 690 at surface 550through a sealing flange located between wellhead 690 and overburden540. The sealing flange may substantially inhibit fluid from escapingfrom opening 514 to surface 550. Lead-in conductor 572 and lead-outconductor 606 may be coupled to elongated members using a cold pintransition conductor. The cold pin transition conductor may include aninsulated conductor of substantially low resistance such thatsubstantially no heat may be generated by the cold pin transitionconductor. The cold pin transition conductor may be coupled to lead-inconductor 572, lead-out conductor 606, and/or elongated members 600 byany splicing or welding methods known in the art. The cold pintransition conductor may provide a temperature transition betweenlead-in conductor 572, lead-out conductor 606, and/or elongated members600. The cold pin transition conductor may be further configured asdescribed in any of the embodiments herein. Lead-in conductor 572 andlead-out conductor 606 may be made of low resistance conductors suchthat substantially no heat may be generated from electrical currentpassing through lead-in conductor 572 and lead-out conductor 606.

[0427] Weld beads may be placed beneath the centralizers 602 on thesupport member 604 to fix the position of the centralizers. Weld beadsmay be placed on the elongated members 600 above the uppermostcentralizer to fix the position of the elongated members relative to thesupport member (other types of connecting mechanisms may also be used).When heated, the elongated member may thermally expand downwards. Theelongated member may be formed of different metals at differentlocations along a length of the elongated member to allow relativelylong lengths to be formed. For example, a “U” shaped elongated membermay include a first length formed of 310 stainless steel, a secondlength formed of 304 stainless steel welded to the first length, and athird length formed of 310 stainless steel welded to the second length.310 stainless steel is more resistive than 304 stainless steel and maydissipate approximately 25% more energy per unit length than 304stainless steel of the same dimensions. 310 stainless steel may be morecreep resistant than 304 stainless steel The first length and the thirdlength may be formed with cross sectional areas that allow the firstlength and third lengths to dissipate as much heat as a smaller crossarea section of 304 stainless steel. The first and third lengths may bepositioned close to the wellhead 690. The use of different types ofmetal may allow the formation of long elongated members. The differentmetals may be, but are not limited to, 617 Inconel, HR120, 316 stainlesssteel, 310 stainless steel, and 304 stainless steel.

[0428] Packing material 542 may be placed between overburden casing 541and opening 514. Packing material 542 may be configured to inhibit fluidflowing from opening 514 to surface 550 and to inhibit correspondingheat losses towards the surface. Packing material 542 may be furtherconfigured as described herein. Overburden casing 541 may be placed incement 544 in overburden 540 of formation 516. Overburden casing 541 maybe further configured as described herein. Surface conductor 545 may bedisposed in cement 544. Surface conductor 545 may be configured asdescribed herein. Support member 604 may be coupled to wellhead 690 atsurface 550 of formation 516. Centralizer 581 may be configured tomaintain a location of support member 604 within overburden casing 541.Centralizer 581 may be further configured as described herein.Electrical current may be supplied to elongated members 600 to generateheat. Heat generated from elongated members 600 may radiate withinopening 514 to heat at least a portion of formation 516.

[0429] The oxidizing fluid may be provided along a length of theelongated members 600 from oxidizing fluid source 508. The oxidizingfluid may inhibit carbon deposition on or proximate to the elongatedmembers. For example, the oxidizing fluid may react with hydrocarbons toform carbon dioxide, which may be removed from the opening. Openings 605in support member 604 may be configured to provide a flow of theoxidizing fluid along the length of elongated members 600. Openings 605may be critical flow orifices as configured and described herein.Alternatively, a tube may be disposed proximate to elongated members 600to control the pressure in the formation as described in aboveembodiments. In another embodiment, a tube may be disposed proximate toelongated members 600 to provide a flow of oxidizing fluid into opening514. Also, at least one of elongated members 600 may include a tubehaving openings configured to provide the flow of oxidizing fluid.Without the flow of oxidizing fluid, carbon deposition may occur on orproximate to elongated members 600 or on insulated centralizers 602,thereby causing shorting between elongated members 600 and insulatedcentralizers 602 or hot spots along elongated members 600. The oxidizingfluid may be used to react with the carbon in the formation as describedherein. The heat generated by reaction with the carbon may complement orsupplement the heat generated electrically.

[0430] In an embodiment, a plurality of elongated members may besupported on a support member disposed in an opening. The plurality ofelongated members may be electrically coupled in either a series orparallel configuration. A current and voltage applied to the pluralityof elongated members may be selected such that the cost of theelectrical supply of power at the surface in conjunction with the costof the plurality of elongated members may be minimized. In addition, anoperating current and voltage may be chosen to optimize a cost of inputelectrical energy in conjunction with a material cost of the elongatedmembers. The elongated members may be configured to generate and radiateheat as described herein. The elongated members may be installed inopening 514 as described herein.

[0431] In an embodiment, a bare metal elongated member may be formed ina “U” shape (or hairpin) and the member may be suspended from a wellheador from a positioner placed at or near an interface between theoverburden and the formation to be heated. In certain embodiments, thebare metal heaters are formed of rod stock. Cylindrical, high aluminaceramic electrical insulators may be placed over legs of the elongatedmembers. Tack welds along lengths of the legs may fix the position ofthe insulators. The insulators may inhibit the elongated member fromcontacting the formation or a well casing (if the elongated member isplaced within a well casing). The insulators may also inhibit legs ofthe “U” shaped members from contacting each other. High alumina ceramicelectrical insulators may be purchased from Cooper Industries (Houston,Tex.). In an embodiment, the “U” shaped member may be formed ofdifferent metals having different cross sectional areas so that theelongated members may be relatively long and may dissipate substantiallythe same amount of heat per unit length along the entire length of theelongated member. The use of different welded together sections mayresult in an elongated member that has large diameter sections near atop of the elongated member and a smaller diameter section or sectionslower down a length of the elongated member. For example, an embodimentof an elongated member has two ⅞ inch (2.2 cm) diameter first sections,two ½ inch (1.3 cm) middle sections, and a ⅜ inch (0.95 cm) diameterbottom section that is bent into a “U” shape. The elongated member maybe made of materials with other cross section shapes such as ovals,squares, rectangles, triangles, etc. The sections may be formed ofalloys that will result in substantially the same heat dissipation perunit length for each section.

[0432] In some embodiments, the cross sectional area and/or the metalused for a particular section may be chosen so that a particular sectionprovides greater (or lesser) heat dissipation per unit length than anadjacent section. More heat dissipation per unit length may be providednear an interface between a hydrocarbon layer and a non-hydrocarbonlayer (e.g., the overburden and the coal formation) to counteract endeffects and allow for more uniform heat dissipation into the coalformation. A higher heat dissipation may also be located at a lower endof an elongated member to counteract end effects and allow for moreuniform heat dissipation.

[0433]FIG. 26 illustrates an embodiment of a surface combustorconfigured to heat a section of a coal formation. Fuel fluid 611 may beprovided into burner 610 through conduit 617. An oxidizing fluid may beprovided into burner 610 from oxidizing fluid source 508. Fuel fluid 611may be oxidized with the oxidizing fluid in burner 610 to form oxidationproducts 613. Fuel fluid 611 may include, for example, hydrogen. Fuelfluid 611 may also include methane or any other hydrocarbon fluids.Burner 610 may be located external to formation 516 or within an opening614 in the coal formation 516. Flame 618 may be configured to heat fuelfluid 611 to a temperature sufficient to support oxidation in burner610. Flame 618 may be configured to heat fuel fluid 611 to a temperatureof about 1425° C. Flame 618 may be coupled to an end of conduit 617.Flame 618 may be a pilot flame. The pilot flame may be configured toburn with a small flow of fuel fluid 611. Flame 618 may, however, be anelectrical ignition source.

[0434] Oxidation products 613 may be provided into opening 614 withininner conduit 612 coupled to burner 610. Heat may be transferred fromoxidation products 613 through outer conduit 615 into opening 614 and toformation 516 along a length of inner conduit 612. Therefore, oxidationproducts 613 may substantially cool along the length of inner conduit612. For example, oxidation products 613 may have a temperature of about870° C. proximate top of inner conduit 612 and a temperature of about650° C. proximate bottom of inner conduit 612. A section of innerconduit 612 proximate to burner 610 may have ceramic insulator 612 bdisposed on an inner surface of inner conduit 612. Ceramic insulator 612b may be configured to substantially inhibit melting of inner conduit612 and/or insulation 612 a proximate to burner 610. Opening 614 mayextend into the formation a length up to about 550 m below surface 550.

[0435] Inner conduit 612 may be configured to provide oxidation products613 into outer conduit 615 proximate a bottom of opening 614. Innerconduit 612 may have insulation 612 a. FIG. 27 illustrates an embodimentof inner conduit 612 with insulation 612 a and ceramic insulator 612 bdisposed on an inner surface of inner conduit 612. Insulation 612 a maybe configured to substantially inhibit heat transfer between fluids ininner conduit 612 and fluids in outer conduit 615. A thickness ofinsulation 612 a may be varied along a length of inner conduit 612 suchthat heat transfer to formation 516 may vary along the length of innerconduit 612. For example, a thickness of insulation 612 a may be taperedto from a larger thickness to a lesser thickness from a top portion to abottom portion, respectively, of inner conduit 612 in opening 614. Sucha tapered thickness may provide substantially more uniform heating offormation 516 along the length of inner conduit 612 in opening 614.Insulation 612 a may include ceramic and metal materials. Oxidationproducts 613 may return to surface 550 through outer conduit 615. Outerconduit may have insulation 615 a as depicted in FIG. 26. Insulation 615a may be configured to substantially inhibit heat transfer from outerconduit 615 to overburden 540.

[0436] Oxidation products 613 may be provided to an additional burnerthrough conduit 619 at surface 550. Oxidation products 613 may beconfigured as a portion of a fuel fluid in the additional burner. Doingso may increase an efficiency of energy output versus energy input forheating formation 516. The additional burner may be configured toprovide heat through an additional opening in formation 516.

[0437] In some embodiments, an electric heater may be configured toprovide heat in addition to heat provided from a surface combustor. Theelectric heater may be, for example, an insulated conductor heater or aconductor-in-conduit heater as described in any of the aboveembodiments. The electric heater may be configured to provide theadditional heat to a coal formation such that the coal formation may beheated substantially uniformly along a depth of an opening in theformation.

[0438] Flameless combustors such as those described in U.S. Pat. No.5,255,742 to Mikus et al., U.S. Pat. No. 5,404,952 to Vinegar et al.,U.S. Pat. No. 5,862,858 to Wellington et al., and U.S. Pat. No.5,899,269 to Wellington et al., which are incorporated by reference asif fully set forth herein, may be configured to heat a coal formation.

[0439]FIG. 28 illustrates an embodiment of a flameless combustorconfigured to heat a section of the coal formation. The flamelesscombustor may include center tube 637 disposed within inner conduit 638.Center tube 637 and inner conduit 638 may be placed within outer conduit636. Outer conduit 636 may be disposed within opening 514 in formation516. Fuel fluid 621 may be provided into the flameless combustor throughcenter tube 637. Fuel fluid 621 may include any of the fuel fluidsdescribed herein. If a hydrocarbon fuel such as methane is utilized, itmay be mixed with steam to prevent coking in center tube 637. Ifhydrogen is used as the fuel, no steam may be required.

[0440] Center tube 637 may include flow mechanisms 635 (e.g., floworifices) disposed within an oxidation region to allow a flow of fuelfluid 621 into inner conduit 638. Flow mechanisms 635 may control a flowof fuel fluid 621 into inner conduit 638 such that the flow of fuelfluid 621 is not dependent on a pressure in inner conduit 638. Flowmechanisms 635 may have characteristics as described herein. Oxidizingfluid 623 may be provided into the combustor through inner conduit 638.Oxidizing fluid 623 may be provided from oxidizing fluid source 508.Oxidizing fluid 623 may include any of the oxidizing fluids as describedin above embodiments. Flow mechanisms 635 on center tube 637 may beconfigured to inhibit flow of oxidizing fluid 623 into center tube 637.

[0441] Oxidizing fluid 621 may mix with fuel fluid 621 in the oxidationregion of inner conduit 638. Either oxidizing fluid 623 or fuel fluid621, or a combination of both, may be preheated external to thecombustor to a temperature sufficient to support oxidation of fuel fluid621. Oxidation of fuel fluid 621 may provide heat generation withinouter conduit 636. The generated heat may provide heat to at least aportion of a coal formation proximate to the oxidation region of innerconduit 638. Products 625 from oxidation of fuel fluid 621 may beremoved through outer conduit 636 outside inner conduit 638. Heatexchange between the downgoing oxidizing fluid and the upgoingcombustion products in the overburden results in enhanced thermalefficiency. A flow of removed combustion products 625 may be balancedwith a flow of fuel fluid 621 and oxidizing fluid 623 to maintain atemperature above autoignition temperature but below a temperaturesufficient to produce substantial oxides of nitrogen. Also, a constantflow of fluids may provide a substantially uniform temperaturedistribution within the oxidation region of inner conduit 638. Outerconduit 636 may be, for example, a stainless steel tube. In this manner,heating of at least the portion of the coal formation may besubstantially uniform. As described above, the lower operatingtemperature may also provide a less expensive metallurgical costassociated with the heating system.

[0442] Certain heat source embodiments may include an operating systemthat is coupled to any of heat sources such by insulated conductors orother types of wiring. The operating system may be configured tointerface with the heat source. The operating system may receive asignal (e.g., an electromagnetic signal) from a heater that isrepresentative of a temperature distribution of the heat source.Additionally, the operating system may be further configured to controlthe heat source, either locally or remotely. For example, the operatingsystem may alter a temperature of the heat source by altering aparameter of equipment coupled to the heat source. Therefore, theoperating system may monitor, alter, and/or control the heating of atleast a portion of the formation.

[0443] In some embodiments, a heat source as described above may beconfigured to substantially operate without a control and/or operatingsystem. The heat source may be configured to only require a power supplyfrom a power source such as an electric transformer. For example, aconductor-in-conduit heater and/or an elongated member heater mayinclude conductive materials that may be have a thermal property thatself-controls a heat output of the heat source. In this manner, theconductor-in-conduit heater and/or the elongated member heater may beconfigured to operate throughout a temperature range without externalcontrol. A conductive material such as stainless steel may be used inthe heat sources. Stainless steel may have a resistivity that increaseswith temperature, thus, providing a greater heat output at highertemperatures.

[0444] Leakage current of any of the heat sources described herein maybe monitored. For example, an increase in leakage current may showdeterioration in an insulated conductor heater. Voltage breakdown in theinsulated conductor heater may cause failure of the heat source.Furthermore, a current and voltage applied to any of the heat sourcesmay also be monitored. The current and voltage may be monitored toassess/indicate resistance in a heat source. The resistance in the heatsource may be configured to represent a temperature in the heat sourcesince the resistance of the heat source may be known as a function oftemperature. Another alternative method may include monitoring atemperature of a heat source with at least one thermocouple placed in orproximate to the heat source. In some embodiments, a control system maymonitor a parameter of the heat source. The control system may alterparameters of the heat source such that the heat source may provide adesired output such as heating rate and/or temperature increase.

[0445] In some embodiments, a thermowell may be disposed into an openingin a coal formation that includes a heat source. The thermowell may bedisposed in an opening that may or may not have a casing. In the openingwithout a casing, the thermowell may include appropriate metallurgy andthickness such that corrosion of the thermowell is substantiallyinhibited. A thermowell and temperature logging process, such as thatdescribed in U.S. Pat. No. 4,616,705 issued to Stegemeier et al., whichis incorporated by reference as if fully set forth herein, may be usedto monitor temperature. Only selected wells may be equipped withthermowells to avoid expenses associated with installing and operatingtemperature monitors at each heat source.

[0446] In some embodiments, a heat source may be turned down and/or offafter an average temperature in a formation may have reached a selectedtemperature. Turning down and/or off the heat source may reduce inputenergy costs, substantially inhibit overheating of the formation, andallow heat to substantially transfer into colder regions of theformation.

[0447] Certain embodiments include providing heat to a first portion ofa coal formation from one or more heat sources. In addition, certainembodiments may include producing formation fluids from the firstportion, and maintaining a second portion of the formation in asubstantially unheated condition. The second portion may besubstantially adjacent to the first portion of the formation. In thismanner, the second portion may provide structural strength to theformation. Furthermore, heat may also be provided to a third portion ofthe formation. The third portion may be substantially adjacent to thesecond portion and/or laterally spaced from the first portion. Inaddition, formation fluids may be produced from the third portion of theformation. In this manner, a processed formation may have a pattern thatmay resemble, for example, a striped or checkerboard pattern withalternating heated and unheated portions.

[0448] Additional portions of the formation may also include suchalternating heated and unheated portions. In this manner, such patternedheating of a coal formation may maintain structural strength within theformation. Maintaining structural strength within a coal formation maysubstantially inhibit subsidence. Subsidence of a portion of theformation being processed may decrease a permeability of the processedportion due to compaction. In addition, subsidence may decrease the flowof fluids in the formation, which may result in a lower production offormation fluids.

[0449] A pyrolysis temperature range may depend on specific types ofhydrocarbons within the formation. A pyrolysis temperature range mayinclude temperatures, for example, between approximately 250° C. andabout 900° C. Alternatively, a pyrolysis temperature range may includetemperatures between about 250 ° C. to about 400° C. For example, amajority of formation fluids may be produced within a pyrolysistemperature range from about 250° C. to about 400° C. If a coalformation is heated throughout the entire pyrolysis range, the formationmay produce only small amounts of hydrogen towards the upper limit ofthe pyrolysis range. After all of the available hydrogen has beendepleted, little fluid production from the formation would occur.

[0450] Temperature (and average temperatures) within a heated coalformation may vary, depending on, for example, proximity to a heatsource, thermal conductivity and thermal diffusivity of the formation,type of reaction occurring, type of coal formation, and the presence ofwater within the coal formation. A temperature within the coal formationmay be assessed using a numerical simulation model. The numericalsimulation model may assess and/or calculate a subsurface temperaturedistribution. In addition, the numerical simulation model may includeassessing various properties of a subsurface formation under theassessed temperature distribution.

[0451] For example, the various properties of the subsurface formationmay include, but are not limited to, thermal conductivity of thesubsurface portion of the formation and permeability of the subsurfaceportion of the formation. The numerical simulation model may alsoinclude assessing various properties of a fluid formed within asubsurface formation under the assessed temperature distribution. Forexample, the various properties of a formed fluid may include, but arenot limited to, a cumulative volume of a fluid formed at a subsurface ofthe formation, fluid viscosity, fluid density, and a composition of thefluid formed at a subsurface of the formation. Such a simulation may beused to assess the performance of commercial-scale operation of asmall-scale field experiment as described herein. For example, aperformance of a commercial-scale development may be assessed based on,but not limited to, a total volume of product that may be produced froma commercial-scale operation.

[0452] In some embodiments, an in situ conversion process may increase atemperature or average temperature within a coal formation. Atemperature or average temperature increase (ΔT) in a specified volume(V) of the coal formation may be assessed for a given heat input rate(q) over time (t) by the following equation:${\Delta \quad T} = \frac{\sum\left( {q*t} \right)}{C_{V}*\rho_{B}*V}$

[0453] In this equation, an average heat capacity of the formation(C_(v)) and an average bulk density of the formation (ρ_(B)) may beestimated or determined using one or more samples taken from the coalformation.

[0454] In alternate embodiments, an in situ conversion process mayinclude heating a specified volume to a pyrolysis temperature or averagepyrolysis temperature. Heat input rate (q) during a time (t) required toheat the specified volume (V) to a desired temperature increase (ΔT) maybe determined or assessed using the following equation:

Σq*t=ΔT*C _(V)*ρ_(B) *V.

[0455] In this equation, an average heat capacity of the formation(C_(v)) and an average bulk density of the formation (ρ_(B)) may beestimated or determined using one or more samples taken from the coalformation.

[0456] It is to be understood that the above equations can be used toassess or estimate temperatures, average temperatures (e.g., overselected sections of the formation), heat input, etc. Such equations donot take into account other factors (such as heat losses) that wouldalso have some effect on heating and temperatures assessments. Howeversuch factors can ordinarily be addressed with correction factors, as iscommonly done in the art.

[0457] In some embodiments, a portion of a coal formation may be heatedat a heating rate in a range from about 0.1° C./day to about 50° C./day.Alternatively, a portion of a coal formation may be heated at a heatingrate in a range of about 0.1° C./day to about 10° C./day. For example, amajority of hydrocarbons may be produced from a formation at a heatingrate within a range of about 0.1° C./day to about 10° C./day. Inaddition, a coal formation may be heated at a rate of less than about0.7° C./day through a significant portion of a pyrolysis temperaturerange. The pyrolysis temperature range may include a range oftemperatures as described in above embodiments. For example, the heatedportion may be heated at such a rate for a time greater than 50% of thetime needed to span the temperature range, more than 75% of the timeneeded to span the temperature range, or more than 90% of the timeneeded to span the temperature range.

[0458] A rate at which a coal formation is heated may affect thequantity and quality of the formation fluids produced from the coalformation. For example, heating at high heating rates, as is the casewhen a Fischer Assay is conducted, may produce a larger quantity ofcondensable hydrocarbons from a coal formation. The products of such aprocess, however, may be of a significantly lower quality than whenheating using heating rates less than about 10° C./day. Heating at arate of temperature increase less than approximately 10° C./day mayallow pyrolysis to occur within a pyrolysis temperature range in whichproduction of undesirable products and tars may be reduced. In addition,a rate of temperature increase of less than about 3° C./day may furtherincrease the quality of the produced condensable hydrocarbons by furtherreducing the production of undesirable products and further reducingproduction of tars within a coal formation.

[0459] In some embodiments, controlling temperature within a coalformation may involve controlling a heating rate within the formation.For example, controlling the heating rate such that the heating rate maybe less than approximately 3° C./day may provide better control of atemperature within the coal formation.

[0460] An in situ process for hydrocarbons may include monitoring a rateof temperature increase at a production well. A temperature within aportion of a coal formation, however, may be measured at variouslocations within the portion of the coal formation. For example, an insitu process may include monitoring a temperature of the portion at amidpoint between two adjacent heat sources. The temperature may bemonitored over time. In this manner, a rate of temperature increase mayalso be monitored. A rate of temperature increase may affect acomposition of formation fluids produced from the formation. As such, arate of temperature increase may be monitored, altered and/orcontrolled, for example, to alter a composition of formation fluidsproduced from the formation.

[0461] In some embodiments, a power (Pwr) required to generate a heatingrate (h) in a selected volume (V) of a coal formation may be determinedby the following equation:

Pwr=h*V*C _(V)*ρ_(B).

[0462] In this equation, an average heat capacity of the coal formationmay be described as C_(V). The average heat capacity of the coalformation may be a relatively constant value. Average heat capacity maybe estimated or determined using one or more samples taken from a coalformation, or measured in situ using a thermal pulse test. Methods ofdetermining average heat capacity based on a thermal pulse test aredescribed by I. Berchenko, E. Detournay, N. Chandler, J. Martino, and E.Kozak, “In-situ measurement of some thermoporoelastic parameters of agranite” in Poromechanics, A Tribute to Maurice A. Biot, pages 545-550,Rotterdam, 1998 (Balkema), which is incorporated by reference as iffully set forth herein.

[0463] In addition, an average bulk density of the coal formation may bedescribed as ρ_(B). The average bulk density of the coal formation maybe a relatively constant value. Average bulk density may be estimated ordetermined using one or more samples taken from a coal formation. Incertain embodiments the product of average heat capacity and averagebulk density of the coal formation may be a relatively constant value(such product can be assessed in situ using a thermal pulse test). Adetermined power may be used to determine heat provided from a heatsource into the selected volume such that the selected volume may beheated at a heating rate, h. For example, a heating rate may be lessthan about 3° C./day, and even less than about 2° C./day. In thismanner, a heating rate within a range of heating rates may be maintainedwithin the selected volume. It is to be understood that in this context“power” is used to describe energy input per time. The form of suchenergy input may, however, vary as described herein (i.e., energy may beprovided from electrical resistance heaters, combustion heaters, etc.).

[0464] The heating rate may be selected based on a number of factorsincluding, but not limited to, the maximum temperature possible at thewell, a predetermined quality of formation fluids that may be producedfrom the formation, etc. A quality of hydrocarbon fluids may be definedby an API gravity of condensable hydrocarbons, by olefin content, by thenitrogen, sulfur and/or oxygen content, etc. In an embodiment, heat maybe provided to at least a portion of a coal formation to produceformation fluids having an API gravity of greater than about 20°. TheAPI gravity may vary, however, depending on, for example, the heatingrate and a pressure within the portion of the formation.

[0465] In some embodiments, subsurface pressure in a coal formation maycorrespond to the fluid pressure generated within the formation. Heatinghydrocarbons within a coal formation may generate fluids, for example,by pyrolysis. The generated fluids may be vaporized within theformation. Fluids that contribute to the increase in pressure mayinclude, but are not limited to, fluids produced during pyrolysis andwater vaporized during heating. The produced pyrolysis fluids mayinclude, but are not limited to, hydrocarbons, water, oxides of carbon,ammonia, molecular nitrogen, and molecular hydrogen. Therefore, astemperatures within a selected section of a heated portion of theformation increase, a pressure within the selected section may increaseas a result of increased fluid generation and vaporization of water.

[0466] In some embodiments, pressure within a selected section of aheated portion of a coal formation may vary depending on, for example,depth, distance from a heat source, a richness of the hydrocarbonswithin the coal formation, and/or a distance from a producer well.Pressure within a formation may be determined at a number of differentlocations, which may include but may not be limited to, at a wellheadand at varying depths within a wellbore. In some embodiments, pressuremay be measured at a producer well. In alternate embodiments, pressuremay be measured at a heater well.

[0467] Heating of a coal formation to a pyrolysis temperature range mayoccur before substantial permeability has been generated within the coalformation. An initial lack of permeability may prevent the transport ofgenerated fluids from a pyrolysis zone within the formation. In thismanner, as heat is initially transferred from a heat source to a coalformation, a fluid pressure within the coal formation may increaseproximate to a heat source. Such an increase in fluid pressure may becaused by, for example, generation of fluids during pyrolysis of atleast some hydrocarbons in the formation. The increased fluid pressuremay be released, monitored, altered, and/or controlled through such aheat source. For example, the heat source may include a valve asdescribed in above embodiments. Such a valve may be configured tocontrol a flow rate of fluids out of and into the heat source. Inaddition, the heat source may include an open hole configuration throughwhich pressure may be released.

[0468] Alternatively, pressure generated by expansion of pyrolysisfluids or other fluids generated in the formation may be allowed toincrease although an open path to the production well or any otherpressure sink may not yet exist in the formation. In addition, a fluidpressure may be allowed to increase to a lithostatic pressure. Fracturesin the coal formation may form when the fluid pressure equals or exceedsthe lithostatic pressure. For example, fractures may form from a heatsource to a production well. The generation of fractures within theheated portion may reduce pressure within the portion due to theproduction of formation fluids through a production well. To maintain aselected pressure within the heated portion, a back pressure may bemaintained at the production well.

[0469] Fluid pressure within a coal formation may vary depending upon,for example, thermal expansion of hydrocarbons, generation of pyrolysisfluids, and withdrawal of generated fluids from the formation. Forexample, as fluids are generated within the formation a fluid pressurewithin the pores may increase. Removal of generated fluids from theformation may decrease a fluid pressure within the formation.

[0470] In an embodiment, a pressure may be increased within a selectedsection of a portion of a coal formation to a selected pressure duringpyrolysis. A selected pressure may be within a range from about 2 barsabsolute to about 72 bars absolute or, in some embodiments, 2 barsabsolute to 36 bars absolute. Alternatively, a selected pressure may bewithin a range from about 2 bars absolute to about 18 bars absolute. Forexample, in certain embodiments, a majority of hydrocarbon fluids may beproduced from a formation having a pressure within a range from about 2bars absolute to about 18 bars absolute. The pressure during pyrolysismay vary or be varied. The pressure may be varied to alter and/orcontrol a composition of a formation fluid produced, to control apercentage of condensable fluid as compared to non-condensable fluid,and/or to control an API gravity of fluid being produced. For example,decreasing pressure may result in production of a larger condensablefluid component, and the fluid may contain a larger percentage ofolefins, and vice versa.

[0471] It is believed that pyrolyzing at reduced temperature andincreased pressure may decrease an olefin to paraffin ratio in producedfluids. Pyrolyzing coal for a longer period of time, which may beaccomplished by increasing pressure within the system, tends to resultin a lower average molecular weight oil and higher API gravity. Inaddition, production of gas may increase and a non-volatile coke may beformed.

[0472] In addition, it is believed that operating at high pressure and apyrolysis temperature at the lower end of the pyrolysis zone tends todecrease the fraction of fluids with carbon numbers greater than 25produced from the coal.

[0473] It is believed that lower temperatures and/or increased partialpressure of hydrogen in the coal formation will tend to produce lessolefins in the produced hydrocarbon fluids. In addition, lowertemperatures and/or higher partial pressures of hydrogen also tend toincrease the atomic hydrogen to atomic carbon ratio in the producedhydrocarbon fluids.

[0474] It is believed that at higher pyrolysis temperatures productionof oil liquids tends to be higher than at the lower pyrolysistemperatures. In addition, high pressures tend to decrease the quantityof oil liquids produced from a coal formation. Operating an in situconversion process at low pressures and high temperatures may produce ahigher quantity of oil liquids than operating at low temperatures andhigh pressures.

[0475] In certain embodiments, pressure within a portion of a coalformation will increase due to fluid generation within the heatedportion. In addition, such increased pressure may be maintained withinthe heated portion of the formation. For example, increased pressurewithin the formation may be maintained by bleeding off a generatedformation fluid through heat sources and/or by controlling the amount offormation fluid produced from the formation through production wells.Maintaining increased pressure within a formation inhibits formationsubsidence. In addition, maintaining increased pressure within aformation tends to reduce the required sizes of collection conduits thatare used to transport condensable hydrocarbons. Furthermore, maintainingincreased pressure within the heated portion may reduce and/orsubstantially eliminate the need to compress formation fluids at thesurface because the formation products will usually be produced athigher pressure. Maintaining increased pressure within a formation mayalso facilitate generation of electricity from produced non-condensablefluid. For example, the produced non-condensable fluid may be passedthrough a turbine to generate electricity.

[0476] Increased pressure in the formation may also be maintained toproduce more and/or improved formation fluids. In certain embodiments,significant amounts (e.g., a majority) of the formation fluids producedfrom a formation within the pyrolysis pressure range may includenon-condensable hydrocarbons. Pressure may be selectively increasedand/or maintained within the formation, and formation fluids can beproduced at or near such increased and/or maintained pressures. Aspressure within a formation is increased, formation fluids produced fromthe formation will, in many instances, include a larger portion ofnon-condensable hydrocarbons. In this manner, a significant amount(e.g., a majority) of the formation fluids produced at such a pressuremay include a lighter and higher quality condensable hydrocarbons thanformation fluids produced at a lower pressure.

[0477] In addition, a pressure may be maintained within a heated portionof a coal formation to substantially inhibit production of formationfluids having carbon numbers greater than, for example, about 25. Forexample, increasing a pressure within the portion of the coal formationmay increase a boiling point of a fluid within the portion. Such anincrease in the boiling point of a fluid may substantially inhibitproduction of formation fluids having relatively high carbon numbers,and/or production of multi-ring hydrocarbon compounds, because suchformation fluids tend to remain in the formation as liquids until theycrack.

[0478] In addition, increasing a pressure within a portion of a coalformation may result in an increase in API gravity of formation fluidsproduced from the formation. Higher pressures may increase production ofshorter chain hydrocarbon fluids, which may have higher API gravityvalues.

[0479] In an embodiment, a pressure within a heated portion of theformation may surprisingly increase the quality of relatively highquality pyrolyzation fluids, the quantity of relatively high qualitypyrolyzation fluids, and/or vapor phase transport of the pyrolyzationfluids within the formation. Increasing the pressure often permitsproduction of lower molecular weight hydrocarbons since such lowermolecular weight hydrocarbons will more readily transport in the vaporphase in the formation. Generation of lower molecular weighthydrocarbons (and corresponding increased vapor phase transport) isbelieved to be due, in part, to autogenous generation and reaction ofhydrogen within a portion of the coal formation. For example,maintaining an increased pressure may force hydrogen generated in theheated portion into a liquid phase (e.g. by dissolving). In addition,heating the portion to a temperature within a pyrolysis temperaturerange may pyrolyze at least some of the hydrocarbons within theformation to generate pyrolyzation fluids in the liquid phase. Thegenerated components may include a double bond and/or a radical. H₂ inthe liquid phase may reduce the double bond of the generatedpyrolyzation fluids, thereby reducing a potential for polymerization ofthe generated pyrolyzation fluids. In addition, hydrogen may alsoneutralize radicals in the generated pyrolyzation fluids. Therefore, H₂in the liquid phase may substantially inhibit the generated pyrolyzationfluids from reacting with each other and/or with other compounds in theformation. In this manner, shorter chain hydrocarbons may enter thevapor phase and may be produced from the formation.

[0480] Increasing the formation pressure to increase the amount ofpyrolyzation fluids in the vapor phase may significantly reduce thepotential for coking within the selected section of the formation. Acoking reaction may occur in the liquid phase. Since many of thegenerated components may be transformed into short chain hydrocarbonsand may enter the vapor phase, coking within the selected section maydecrease.

[0481] Increasing the formation pressure to increase the amount ofpyrolyzation fluids in the vapor phase is also beneficial because doingso permits increased recovery of lighter (and relatively high quality)pyrolyzation fluids. In general, pyrolyzation fluids are more quicklyproduced, with less residuals, when such fluids are in the vapor phaserather than in the liquid phase. Undesirable polymerization reactionsalso tend to occur more frequently when the pyrolyzation fluids are inthe liquid phase instead of the vapor phase. In addition, whenpyrolyzation fluids are produced in the vapor phase, fewer productionwells/area are needed, thereby reducing project costs.

[0482] In an embodiment, a portion of a coal formation may be heated toincrease a partial pressure of H₂. In some embodiments, an increased H₂partial pressure may include H₂ partial pressures in a range from about1 bar absolute to about 7 bars absolute. Alternatively, an increased H₂partial pressure range may include H₂ partial pressures in a range fromabout 5 bars absolute to about 7 bars absolute. For example, a majorityof hydrocarbon fluids may be produced within a range of about 5 barsabsolute to about 7 bars absolute. A range of H₂ partial pressureswithin the pyrolysis H₂ partial pressure range may vary, however,depending on, for example, a temperature and a pressure of the heatedportion of the formation.

[0483] Maintaining a H₂ partial pressure within the formation of greaterthan atmospheric pressure may increase an API value of producedcondensable hydrocarbon fluids. For example, maintaining such a H₂partial pressure may increase an API value of produced condensablehydrocarbon fluids to greater than about 25 or, in some instances,greater than about 30. Maintaining such a H₂ partial pressure within aheated portion of a coal formation may increase a concentration of H₂within the heated portion such that H₂ may be available to react withpyrolyzed components of the hydrocarbons. Reaction of H₂ with thepyrolyzed components of hydrocarbons may reduce polymerization ofolefins into tars and other cross-linked, difficult to upgrade,products. Such products may have lower API gravity values. Therefore,production of hydrocarbon fluids having low API gravity values may besubstantially inhibited.

[0484] A valve may be configured to maintain, alter, and/or control apressure within a heated portion of a coal formation. For example, aheat source disposed within a coal formation may be coupled to a valve.The valve may be configured to release fluid from the formation throughthe heater source. In addition, a pressure valve may be coupled to aproduction well, which may be disposed within the coal formation. Insome embodiments, fluids released by the valves may be collected andtransported to a surface unit for further processing and/or treatment.

[0485] An in situ conversion process for coal may include providing heatto a portion of a coal formation, and controlling a temperature, rate oftemperature increase, and/or a pressure within the heated portion. Forexample, a pressure within the heated portion may be controlled usingpressure valves disposed within a heater well or a production well asdescribed herein. A temperature and/or a rate of temperature increase ofthe heated portion may be controlled, for example, by altering an amountof energy supplied to one or more heat sources.

[0486] Controlling a pressure and a temperature within a coal formationwill, in most instances, affect properties of the produced formationfluids. For example, a composition or a quality of formation fluidsproduced from the formation may be altered by altering an averagepressure and/or an average temperature in the selected section of theheated portion. The quality of the produced fluids may be defined by aproperty which may include, but may not be limited to, API gravity,percent olefins in the produced formation fluids, ethene to ethaneratio, atomic hydrogen to carbon ratio, percent of hydrocarbons withinproduced formation fluids having carbon numbers greater than 25, totalequivalent production (gas and liquid), total liquids production, and/orliquid yield as a percent of Fischer Assay. For example, controlling thequality of the produced formation fluids may include controlling averagepressure and average temperature in the selected section such that theaverage assessed pressure in the selected section may be greater thanthe pressure (p) as set forth in the form of the following relationshipfor an assessed average temperature (T) in the selected section:

[0487] $p = \exp^{\lbrack{\frac{A}{T} + B}\rbrack}$

[0488] where p is measured in psia (pounds per square inch absolute), Tis measured in degrees Kelvin, A and B are parameters dependent on thevalue of the selected property. An assessed average temperature may bedetermined as described herein.

[0489] The relationship given above may be rewritten such that thenatural log of pressure may be a linear function of an inverse oftemperature. This form of the relationship may be rewritten:

ln(p)=A/T+B.

[0490] In a plot of the absolute pressure as a function of thereciprocal of the absolute temperature, A is the slope and B is theintercept. The intercept B is defined to be the natural logarithm of thepressure as the reciprocal of the temperature approaches zero.Therefore, the slope and intercept values (A and B) of thepressure-temperature relationship may be determined from twopressure-temperature data points for a given value of a selectedproperty. The pressure-temperature data points may include an averagepressure within a formation and an average temperature within theformation at which the particular value of the property was, or may be,produced from the formation. For example, the pressure-temperature datapoints may be obtained from an experiment such as a laboratoryexperiment or a field experiment.

[0491] A relationship between the slope parameter, A, and a value of aproperty of formation fluids may be determined. For example, values of Amay be plotted as a function of values of a formation fluid property. Acubic polynomial may be fitted to these data. For example, a cubicpolynomial relationship such asA=a₁*(property)³+a₂*(property)²+a₃*(property)+a₄ may be fitted to thedata, where a₁, a₂, a₃, and a₄ are empirical constants that may describea relationship between the first parameter, A, and a property of aformation fluid. Alternatively, relationships having other functionalforms such as another order polynomial or a logarithmic function may befitted to the data. In this manner, a₁, a₂, . . . , may be estimatedfrom the results of the data fitting. Similarly, a relationship betweenthe second parameter, B, and a value of a property of formation fluidsmay be determined. For example, values of B may be plotted as a functionof values of a property of a formation fluid. A cubic polynomial mayalso be fitted to the data. For example, a cubic polynomial relationshipsuch as B=b₁*(property)³+b₂*(property)²+b₃*(property)+b₄ may be fittedto the data, where b₁, b₂, b₃, and b4 are empirical constants that maydescribe a relationship between the parameter B, and the value of aproperty of a formation fluid. As such, b₁, b₂, b₃, and b₄ may beestimated from results of fitting the data. To determine an averagepressure and an average temperature that may be used to produce aformation fluid having a selected property, the value of the selectedproperty and the empirical constants as described above may be used todetermine values for the first parameter A, and the second parameter B,according to the following relationships:

A=a ₁*(property)³ +a ₂*(property)² +a ₃*(property)+a ₄

B=b ₁*(property)³ +b ₂*(property)² +b ₃*(property)+b ₄

[0492] The determined values for the parameter A, and the parameter B,may be used to determine an average pressure in the selected section ofthe formation using an assessed average temperature, T, in the selectedsection. The assessed average temperature may be determined as describedherein. For example, an average pressure of the selected section may bedetermined by the relationship:

p=exp[(A/T)+B],

[0493] in which p is measured in psia, and T is measured in degreesKelvin. Alternatively, an average absolute pressure of the selectedsection, measured in bars, may be determined using the followingrelationship:

P _(bars)=exp[(A/T)+B−2.6744].

[0494] In this manner, an average pressure within the selected sectionmay be controlled such that an average pressure within the selectedsection is adjusted to the average pressure as determined above, inorder to produce a formation fluid from the selected section having aselected property.

[0495] Alternatively, the determined values for the parameter A, and theparameter B, may be used to determine an average temperature in theselected section of the formation using an assessed average pressure, p,in the selected section. The assessed average pressure may be determinedas described herein. Therefore, using the relationship described above,an average temperature within the selected section may be controlled toapproximate the calculated average temperature in order to producehydrocarbon fluids having a selected property.

[0496] As described herein, a composition of formation fluids producedfrom a formation may be varied by altering at least one operatingcondition of an in situ conversion process for coal. In addition, atleast one operating condition may be determined by using acomputer-implemented method. For example, an operating condition mayinclude, but is not limited to, a pressure in the formation, atemperature in the formation, a heating rate of the formation, a powersupplied to a heat source, and/or a flow rate of a synthesis gasgenerating fluid. The computer-implemented method may include measuringat least one property of the formation. For example, measured propertiesmay include a thickness of a layer containing coal, vitrinitereflectance, hydrogen content, oxygen content, moisture content,depth/width of the coal formation, and other properties otherwisedescribed herein.

[0497] At least one measured property may be inputted into a computerexecutable program. The program may be operable to determine at leastone operating condition from a measured property. In addition, at leastone property of selected formation fluids may be input into the program.For example, properties of selected formation fluids may include, butare not limited to, API gravity, olefin content, carbon numberdistribution, ethene to ethane ratio, and atomic carbon to hydrogenratio. The program may also be operable to determine at least oneoperating condition from a property of the selected formation fluids. Inthis manner, an operating condition of an in situ conversion process maybe altered to be approximate at least one determined operating conditionsuch that production of selected formation fluids from the formation mayincrease.

[0498] In an embodiment, a computer-implemented method may be used todetermine at least one property of a formation fluid that may beproduced from a coal formation for a set of operating conditions as afunction of time. The method may include measuring at least one propertyof the formation and providing at least the one measured property to acomputer program as described herein. In addition, one or more sets ofoperating conditions may also be provided to the computer program. Atleast one of the operating conditions may include, for example, aheating rate or a pressure. One or more sets of operating conditions mayinclude currently used operating conditions (in an in situ conversionprocess) or operating conditions being considered for an in situconversion process. The computer program may be operable to determine atleast one property of a formation fluid that may be produced by an insitu conversion process for coal as a function of time using at leastone set of operating conditions and at least one measured property ofthe formation. Furthermore, the method may include comparing adetermined property of the fluid to a selected property. In this manner,if multiple determined properties are generated by the computer program,then the determined property that differs least from a selected propertymay be determined.

[0499] Formation fluid properties may vary depending on a location of aproduction well in the formation. For example, a location of aproduction well with respect to a location of a heat source in theformation may affect the composition of formation fluid produced from aformation. In addition, a distance between a production well and a heatsource in a formation may be varied to alter the composition offormation fluid produced from a formation. Decreasing a distance betweena production well and a heat source may increase a temperature at theproduction well. In this manner, a substantial portion of pyrolyzationfluids flowing through a production well may in some instances crack tonon-condensable compounds due to increased temperature at a productionwell. Therefore, a location of a production well with respect to a heatsource may be selected to increase a non-condensable gas fraction of theproduced formation fluids. In addition, a location of a production wellwith respect to a heat source may be selected such that anon-condensable gas fraction of produced formation fluids may be largerthan a condensable gas fraction of the produced formation fluids.

[0500] A carbon number distribution of a produced formation fluid mayindicate a quality of the produced formation fluid. In general,condensable hydrocarbons with low carbon numbers are considered to bemore valuable than condensable hydrocarbons having higher carbonnumbers. Low carbon numbers may include, for example, carbon numbersless than about 25. High carbon numbers may include carbon numbersgreater than about 25. In an embodiment, an in situ conversion processfor coal may include providing heat to at least a portion of a formationand allowing heat to transfer such that heat may produce pyrolyzationfluids such that a majority of the pyrolyzation fluids have carbonnumbers of less than approximately 25.

[0501] In an embodiment, an in situ conversion process for coal mayinclude providing heat to at least a portion of a coal formation at arate sufficient to alter and/or control production of olefins. Forexample, the process may include heating the portion at a rate toproduce formation fluids having an olefin content of less than about 10%by weight of condensable hydrocarbons of the formation fluids. Reducingolefin production may substantially reduce coating of a pipe surface bysuch olefins, thereby reducing difficulty associated with transportinghydrocarbons through such piping. Reducing olefin production may alsotend to inhibit polymerization of hydrocarbons during pyrolysis, therebyincreasing permeability in the formation and/or enhancing the quality ofproduced fluids (e.g., by lowering the carbon number distribution,increasing API gravity, etc.).

[0502] In some embodiments, however, the portion may be heated at a rateto selectively increase the olefin content of condensable hydrocarbonsin the produced fluids. For example, olefins may be separated from suchcondensable hydrocarbons and may be used to produce additional products.

[0503] In some embodiments, the portion may be heated at a rate toselectively increase the content of phenol and substituted phenols ofcondensable hydrocarbons in the produced fluids. For example, phenoland/or substituted phenols may be separated from such condensablehydrocarbons and may be used to produce additional products. Theresource may, in some embodiments, be selected to enhance production ofphenol and/or substituted phenols.

[0504] Hydrocarbons in the produced fluids may include a mixture of anumber of different components, some of which are condensable and someof which are not. The fraction of non-condensable hydrocarbons withinthe produced fluid may be altered and/or controlled by altering,controlling, and/or maintaining a temperature within a pyrolysistemperature range in a heated portion of the coal formation.Additionally, the fraction of non-condensable hydrocarbons within theproduced fluids may be altered and/or controlled by altering,controlling, and/or maintaining a pressure within the heated portion. Insome embodiments, surface facilities may be configured to separatecondensable and non-condensable hydrocarbons of a produced fluid.

[0505] In some embodiments, the non-condensable hydrocarbons mayinclude, but are not limited to, hydrocarbons having less than about 5carbon atoms, H₂, CO₂, ammonia, H₂S, N₂ and/or CO. In certainembodiments, non-condensable hydrocarbons of a fluid produced from aportion of a coal formation may have a weight ratio of hydrocarbonshaving carbon numbers from 2 through 4 (“C₂₋₄” hydrocarbons) to methaneof greater than about 0.3, greater than about 0.75, or greater thanabout 1 in some circumstances. For example, non-condensable hydrocarbonsof a fluid produced from a portion of a coal formation may have a weightratio of hydrocarbons having carbon numbers from 2 through 4, tomethane, of greater than approximately 0.3.

[0506] Such weight ratios of C₂₋₄ hydrocarbons to methane are believedto be beneficial as compared to similar weight ratios produced fromother formations. Such weight ratios indicate higher amounts ofhydrocarbons with 2, 3, and/or 4 carbons (e.g., ethane, propane, andbutane) than is normally present in gases produced from formations. Suchhydrocarbons are often more valuable. Production of hydrocarbons withsuch weight ratios is believed to be due to the conditions applied tothe formation during pyrolysis (e.g., controlled heating and/or pressureused in reducing environments, or at least non-oxidizing environments).It is believed that in such conditions longer chain hydrocarbons can bemore easily broken down to form substantially smaller (and in many casesmore saturated) compounds such as C₂₋₄ hydrocarbons. The C₂₋₄hydrocarbons to methane weight ratio may vary depending on, for example,a temperature of the heated portion and a heating rate of the heatedportion.

[0507] In certain embodiments, the API gravity of the hydrocarbons in afluid produced from a coal formation may be approximately 20 or above(e.g., 25, 30, 35, 40, 50, etc.).

[0508] Methane and at least a portion of ethane may be separated fromnon-condensable hydrocarbons in the produced fluid and may be utilizedas natural gas. A portion of propane and butane may be separated fromnon-condensable hydrocarbons of the produced fluid. In addition, theseparated propane and butane may be utilized as fuels or as feedstocksfor producing other hydrocarbons. A portion of the produced fluid havingcarbon numbers less than 4 may be reformed, as described herein, in theformation to produce additional H₂ and/or methane. In addition, ethane,propane, and butane may be separated from the non-condensablehydrocarbons and may be used to generate olefins.

[0509] The non-condensable hydrocarbons of fluid produced from a coalformation may have a H₂ content of greater than about 5% by weight,greater than 10% by weight, or even greater than 15% by weight. The H₂may be used, for example, as a fuel for a fuel cell, to hydrogenatehydrocarbon fluids in situ, and/or to hydrogenate hydrocarbon fluids exsitu. In addition, presence of H₂ within a formation fluid in a heatedsection of a coal formation is believed to increase the quality ofproduced fluids. In certain embodiments, the hydrogen to carbon atomicratio of a produced fluid may be at least approximately 1.7 or above.For example, the hydrogen to carbon atomic ratio of a produced fluid maybe approximately 1.8, approximately 1.9, or greater.

[0510] The non-condensable hydrocarbons may include some hydrogensulfide. The non-condensable hydrocarbons may be treated to separate thehydrogen sulfide from other compounds in the non-condensablehydrocarbons. The separated hydrogen sulfide may be used to produce, forexample, sulfuric acid, fertilizer, and/or elemental sulfur.

[0511] In certain embodiments, fluid produced from a coal formation byan in situ conversion process may include carbon dioxide. Carbon dioxideproduced from the formation may be used, for example, for enhanced oilrecovery, as at least a portion of a feedstock for production of urea,and/or may be reinjected into a coal formation for synthesis gasproduction and/or coal bed methane production.

[0512] Fluid produced from a coal formation by an in situ conversionprocess may include carbon monoxide. Carbon monoxide produced from theformation may be used, for example, as a feedstock for a fuel cell, as afeedstock for a Fischer Tropsch process, as a feedstock for productionof methanol, and/or as a feedstock for production of methane.

[0513] The condensable hydrocarbons of the produced fluids may beseparated from the fluids. In an embodiment, a condensable component mayinclude condensable hydrocarbons and compounds found in an aqueousphase. The aqueous phase may be separated from the condensablecomponent. The ammonia content of the total produced fluids may begreater than about 0.1% by weight of the fluid, greater than about 0.5%by weight of the fluid, and, in some embodiments, up to about 10% byweight of the produced fluids. The ammonia may be used to produce, forexample, urea.

[0514] Certain embodiments of a fluid may be produced in which amajority of hydrocarbons in the produced fluid have a carbon number ofless than approximately 25. Alternatively, less than about 15% by weightof the hydrocarbons in the condensable hydrocarbons have a carbon numbergreater than approximately 25. In some embodiments, less than about 5%by weight of hydrocarbons in the condensable hydrocarbons have a carbonnumber greater than approximately 25, and/or less than about 2% byweight of hydrocarbons in the condensable hydrocarbons have a carbonnumber greater than approximately 25.

[0515] In certain embodiments, a fluid produced from a formation (e.g.,a coal formation) may include oxygenated hydrocarbons. For example,condensable hydrocarbons of the produced fluid may include an amount ofoxygenated hydrocarbons greater than about 5% by weight of thecondensable hydrocarbons. Alternatively, the condensable hydrocarbonsmay include an amount of oxygenated hydrocarbons greater than about 1.0%by weight of the condensable hydrocarbons. Furthermore, the condensablehydrocarbons may include an amount of oxygenated hydrocarbons greaterthan about 1.5% by weight of the condensable hydrocarbons or greaterthan about 2.0% by weight of the condensable hydrocarbons. In anembodiment, the oxygenated hydrocarbons may include, but are not limitedto, phenol and/or substituted phenols. In some embodiments, phenol andsubstituted phenols may have more economic value than other productsproduced from an in situ conversion process. Therefore, an in situconversion process may be utilized to produce phenol and/or substitutedphenols. For example, generation of phenol and/or substituted phenolsmay increase when a fluid pressure within the formation is maintained ata lower pressure.

[0516] In some embodiments, condensable hydrocarbons of a fluid producedfrom a coal formation may also include olefins. For example, an olefincontent of the condensable hydrocarbons may be in a range from about0.1% by weight to about 15% by weight. Alternatively, an olefin contentof the condensable hydrocarbons may also be within a range from about0.1% by weight to about 5% by weight. Furthermore, an olefin content ofthe condensable hydrocarbons may also be within a range from about 0.1%by weight to about 2.5% by weight. An olefin content of the condensablehydrocarbons may be altered and/or controlled by controlling a pressureand/or a temperature within the formation. For example, olefin contentof the condensable hydrocarbons may be reduced by selectively increasingpressure within the formation, by selectively decreasing temperaturewithin the formation, by selectively reducing heating rates within theformation, and/or by selectively increasing hydrogen partial pressuresin the formation. In some embodiments, a reduced olefin content of thecondensable hydrocarbons may be preferred. For example, if a portion ofthe produced fluids is used to produce motor fuels, a reduced olefincontent may be desired.

[0517] In alternate embodiments, a higher olefin content may bepreferred. For example, if a portion of the condensable hydrocarbons maybe sold, a higher olefin content may be preferred due to a high economicvalue of olefin products. In some embodiments, olefins may be separatedfrom the produced fluids and then sold and/or used as a feedstock forthe production of other compounds.

[0518] Non-condensable hydrocarbons of a produced fluid may also includeolefins. For example, an olefin content of the non-condensablehydrocarbons may be gauged using an ethene/ethane molar ratio. Incertain embodiments, the ethene/ethane molar ratio may range from about0.001 to about 0.15.

[0519] Fluid produced from a coal formation may include aromaticcompounds. For example, the condensable hydrocarbons may include anamount of aromatic compounds greater than about 20% by weight or about25% by weight of the condensable hydrocarbons. Alternatively, thecondensable hydrocarbons may include an amount of aromatic compoundsgreater than about 30% by weight of the condensable hydrocarbons. Thecondensable hydrocarbons may also include relatively low amounts ofcompounds with more than two rings in them (e.g., tri-aromatics orabove). For example, the condensable hydrocarbons may include less thanabout 1% by weight or less than about 2% by weight of tri-aromatics orabove in the condensable hydrocarbons. Alternatively, the condensablehydrocarbons may include less than about 5% by weight of tri-aromaticsor above in the condensable hydrocarbons.

[0520] In particular, in certain embodiments, asphaltenes (i.e., largemulti-ring aromatics that may be substantially soluble in hydrocarbons)make up less than about 0.1% by weight of the condensable hydrocarbons.For example, the condensable hydrocarbons may include an asphaltenecomponent of from about 0.0% by weight to about 0.1% by weight or, insome embodiments, less than about 0.3% by weight.

[0521] Condensable hydrocarbons of a produced fluid may also includerelatively large amounts of cycloalkanes. For example, the condensablehydrocarbons may include a cycloalkane component of from about 5% byweight to about 30% by weight of the condensable hydrocarbons.

[0522] In certain embodiments, the condensable hydrocarbons of a fluidproduced from a formation may include compounds containing nitrogen. Forexample, less than about 1% by weight (when calculated on an elementalbasis) of the condensable hydrocarbons may be nitrogen (e.g., typicallythe nitrogen may be in nitrogen containing compounds such as pyridines,amines, amides, carbazoles, etc.).

[0523] In certain embodiments, the condensable hydrocarbons of a fluidproduced from a formation may include compounds containing oxygen. Forexample, in an embodiments, in a fluid produced from a coal formationbetween about 5% by weight and about 30% by weight of the condensablehydrocarbons may typically include oxygen containing compounds such asphenols, substituted phenols, ketones, etc. In some instances, certaincompounds containing oxygen (e.g., phenols) may be valuable and, assuch, may be economically separated from the produced fluid.

[0524] In certain embodiments, condensable hydrocarbons of the fluidproduced from a formation may include compounds containing sulfur. Forexample, less than about 1% by weight (when calculated on an elementalbasis) of the condensable hydrocarbons may be sulfur (e.g., typicallythe sulfur containing compounds may include compounds such asthiophenes, mercaptans, etc.).

[0525] Furthermore, the fluid produced from the formation may includeammonia (typically the ammonia may condense with water, if any, producedfrom the formation). For example, the fluid produced from the formationmay in certain embodiments include about 0.05% or more by weight ofammonia. In some embodiments coal formations may produce larger amountsof ammonia (e.g., up to about 10% by weight of the total fluid producedmay be ammonia).

[0526] In addition, a produced fluid from the formation may also includemolecular hydrogen (H₂). For example, the fluid may include a H₂ contentbetween about 10% to about 80% by volume of the non-condensablehydrocarbons.

[0527] In some embodiments, at least about 15% by weight of a totalorganic carbon content of hydrocarbons in the portion may be transformedinto hydrocarbon fluids.

[0528] A total potential amount of products that may be produced fromhydrocarbons may be determined by a Fischer Assay. The Fischer Assay isa standard method that involves heating a sample of hydrocarbons toapproximately 500° C. in one hour, collecting products produced from theheated sample, and quantifying the products. In an embodiment, a methodfor treating a coal formation in situ may include heating a section ofthe formation to yield greater than about 60% by weight of the potentialamount of products from the hydrocarbons as measured by the FischerAssay.

[0529] In certain embodiments, heating of the selected section of theformation may be controlled to pyrolyze at least about 20% by weight (orin some embodiments about 25% by weight) of the hydrocarbons within theselected section of the formation. Conversion of hydrocarbons within aformation may be limited to inhibit subsidence of the formation.

[0530] Heating at least a portion of a formation may cause at least someof the hydrocarbons within the portion to pyrolyze, thereby forminghydrocarbon fragments. The hydrocarbon fragments may be reactive and mayreact with other compounds in the formation and/or with otherhydrocarbon fragments produced by pyrolysis. Reaction of the hydrocarbonfragments with other compounds and/or with each other, however, mayreduce production of a selected product. A reducing agent in or providedto the portion of the formation during heating, however, may increaseproduction of the selected product. An example of a reducing agent mayinclude, but may not be limited to, H₂. For example, the reducing agentmay react with the hydrocarbon fragments to form a selected product.

[0531] In an embodiment, molecular hydrogen may be provided to theformation to create a reducing environment. A hydrogenation reactionbetween the molecular hydrogen and at least some of the hydrocarbonswithin a portion of the formation may generate heat. The generated heatmay be used to heat the portion of the formation. Molecular hydrogen mayalso be generated within the portion of the formation. In this manner,the generated H₂ may be used to hydrogenate hydrocarbon fluids within aportion of a formation.

[0532] For example, H₂ may be produced from a first portion of the coalformation. The H₂ may be produced as a component of a fluid producedfrom a first portion. For example, at least a portion of fluids producedfrom a first portion of the formation may be provided to a secondportion of the formation to create a reducing environment within thesecond portion. The second portion of the formation may be heated asdescribed herein. In addition, produced H₂ may be provided to a secondportion of the formation. For example, a partial pressure of H₂ withinthe produced fluid may be greater than a pyrolysis H₂ partial pressure,as measured at a well from which the produced fluid may be produced.

[0533] For example, a portion of a coal formation may be heated in areducing environment. The presence of a reducing agent during pyrolysisof at least some of the hydrocarbons in the heated portion may reduce(e.g., at least partially saturate) at least some of the pyrolyzedproduct. Reducing the pyrolyzed product may decrease a concentration ofolefins in hydrocarbon fluids. Reducing the pyrolysis products mayimprove the product quality of the hydrocarbon fluids.

[0534] An embodiment of a method for treating a coal formation in situmay include generating H₂ and hydrocarbon fluids within the formation.In addition, the method may include hydrogenating the generatedhydrocarbon fluids using the H₂ within the formation. In someembodiments, the method may also include providing the generated H₂ to aportion of the formation.

[0535] In an embodiment, a method of treating a portion of a coalformation may include heating the portion such that a thermalconductivity of a selected section of the heated portion increases. Forexample, porosity and permeability within a selected section of theportion may increase substantially during heating such that heat may betransferred through the formation not only by conduction but also byconvection and/or by radiation from a heat source. In this manner, suchradiant and convective transfer of heat may increase an apparent thermalconductivity of the selected section and, consequently, the thermaldiffusivity. The large apparent thermal diffusivity may make heating atleast a portion of a coal formation from heat sources feasible. Forexample, a combination of conductive, radiant, and/or convective heatingmay accelerate heating. Such accelerated heating may significantlydecrease a time required for producing hydrocarbons and maysignificantly increase the economic feasibility of commercialization ofan in situ conversion process. In a further embodiment, the in situconversion process for a coal formation may also include providing heatto the heated portion to increase a thermal conductivity of a selectedsection to greater than about 0.5 W/(m° C.) or about 0.6 W/(m° C.).

[0536] In some embodiments, an in situ conversion process for a coalformation may increase the rank level of coal within a heated portion ofthe coal. The increase in rank level, as assessed by the vitrinitereflectance, of the coal may coincide with a substantial change of thestructure (e.g., molecular changes in the carbon structure) of the coal.The changed structure of the coal may have a higher thermalconductivity.

[0537] Thermal diffusivity within a coal formation may vary dependingon, for example, a density of the coal formation, a heat capacity of theformation, and a thermal conductivity of the formation. As pyrolysisoccurs within a selected section, the coal formation mass may be removedfrom the selected section. The removal of mass may include, but is notlimited to, removal of water and a transformation of hydrocarbons toformation fluids. For example, a lower thermal conductivity may beexpected as water is removed from a coal formation. This effect may varysignificantly at different depths. At greater depths a lithostaticpressure may be higher, and may close certain openings (e.g., cleatsand/or fractures) in the coal. The closure of the coal openings mayincrease a thermal conductivity of the coal. In some embodiments, ahigher thermal conductivity may be observed due to a higher lithostaticpressure.

[0538] In some embodiments, an in situ conversion process may generatemolecular hydrogen during the pyrolysis process. In addition, pyrolysistends to increase the porosity/void spaces in the formation. Void spacesin the formation may contain hydrogen gas generated by the pyrolysisprocess. Hydrogen gas may have about six times the thermal conductivityof nitrogen or air. This may raise the thermal conductivity of theformation.

[0539] Certain embodiments described herein will in many instances beable to economically treat formations that were previously believed tobe uneconomical. Such treatment will be possible because of thesurprising increases in thermal conductivity and thermal diffusivitythat can be achieved with such embodiments. These surprising results areillustrated by the fact that prior literature indicated that certaincoal formations exhibited relatively low values for thermal conductivityand thermal diffusivity when heated. For example, in government reportNo. 8364 by J. M. Singer and R. P. Tye entitled “Thermal, Mechanical,and Physical Properties of Selected Bituminous Coals and Cokes,” U.S.Department of the Interior, Bureau of Mines (1979), the authors reportthe thermal conductivity and thermal diffusivity for four bituminouscoals. This government report includes graphs of thermal conductivityand diffusivity that show relatively low values up to about 400° C.(e.g., thermal conductivity is about 0.2 W/(m° C.) or below, and thermaldiffusivity is below about 1.7×10⁻³ cm²/s). This government reportstates that “coals and cokes are excellent thermal insulators.”

[0540] In contrast, in certain embodiments described herein coal may betreated such that the thermal conductivity and thermal diffusivity aresignificantly higher (e.g., thermal conductivity at or above about 0.5W/(m° C.) and thermal diffusivity at or above 4.1×10⁻³ cm²/s) than wouldbe expected based on previous literature such as government report No.8364. If treated as described in certain embodiments herein, coal doesnot act as “an excellent thermal insulator.” Instead, heat can and doestransfer and/or diffuse into the formation at significantly higher (andbetter) rates than would be expected according to the literature,thereby significantly enhancing economic viability of treating theformation.

[0541] In an embodiment, heating a portion of a coal formation in situto a temperature less than an upper pyrolysis temperature may increasepermeability of the heated portion. For example, permeability mayincrease due to formation of fractures within the heated portion causedby application of heat. As a temperature of the heated portionincreases, water may be removed due to vaporization. The vaporized watermay escape and/or be removed from the formation. Removal of water mayalso increase the permeability of the heated portion. In addition,permeability of the heated portion may also increase as a result ofproduction of hydrocarbons from pyrolysis of at least some of thehydrocarbons within the heated portion on a macroscopic scale. In anembodiment, a permeability of a selected section within a heated portionof a coal formation may be substantially uniform. For example, heatingby conduction may be substantially uniform, and thus a permeabilitycreated by conductive heating may also be substantially uniform. In thecontext of this patent “substantially uniform permeability” means thatthe assessed (e.g., calculated or estimated) permeability of anyselected portion in the formation does not vary by more than a factor of10 from the assessed average permeability of such selected portion.

[0542] Permeability of a selected section within the heated portion ofthe coal formation may also rapidly increase while the selected sectionis heated by conduction. For example, permeability of an impermeablecoal formation may be less than about 1 millidarcy before treatment. Insome embodiments, pyrolyzing at least a portion of a coal formation mayincrease a permeability within a selected section of the portion togreater than about 10 millidarcy, 100 millidarcy, 1 Darcy, 10 Darcy, 20Darcy, or 50 Darcy. Therefore, a permeability of a selected section ofthe portion may increase by a factor of more than about 10, 100, 1,000,or 10,000.

[0543] In some embodiments, superposition (e.g., overlapping) of heatfrom one or more heat sources may result in substantially uniformheating of a portion of a coal formation. Since formations duringheating will typically have temperature profiles throughout them, in thecontext of this patent “substantially uniform” heating means heatingsuch that the temperatures in a majority of the section do not vary bymore than 100° C. from the assessed average temperature in the majorityof the selected section (volume) being treated.

[0544] Substantially uniform heating of the coal formation may result ina substantially uniform increase in permeability. For example, uniformlyheating may generate a series of substantially uniform fractures withinthe heated portion due to thermal stresses generated in the formation.Heating substantially uniformly may generate pyrolysis fluids from theportion in a substantially homogeneous manner. Water removed due tovaporization and production may result in increased permeability of theheated portion. In addition to creating fractures due to thermalstresses, fractures may also be generated due to fluid pressureincrease. As fluids are generated within the heated portion a fluidpressure within the heated portion may also increase. As the fluidpressure approaches a lithostatic pressure of the heated portion,fractures may be generated. Substantially uniform heating andhomogeneous generation of fluids may generate substantially uniformfractures within the heated portion. In some embodiments, a permeabilityof a heated section of a coal formation may not vary by more than afactor of about 10.

[0545] Removal of hydrocarbons due to treating at least a portion of acoal formation, as described in any of the above embodiments, may alsooccur on a microscopic scale. Hydrocarbons may be removed frommicropores within the portion due to heating. Micropores may begenerally defined as pores having a cross-sectional dimension of lessthan about 1000 Å. In this manner, removal of solid hydrocarbons mayresult in a substantially uniform increase in porosity within at least aselected section of the heated portion. Heating the portion of a coalformation, as described in any of the above embodiments, maysubstantially uniformly increase a porosity of a selected section withinthe heated portion. In the context of this patent “substantially uniformporosity” means that the assessed (e.g., calculated or estimated)porosity of any selected portion in the formation does not vary by morethan about 25% from the assessed average porosity of such selectedportion.

[0546] Physical characteristics of a portion of a coal formation afterpyrolysis may be similar to those of a porous bed. For example, aportion of a coal formation after pyrolysis may include particles havingsizes of about several millimeters. Such physical characteristics maydiffer from physical characteristics of a coal formation that may besubjected to injection of gases that burn hydrocarbons in order to heatthe hydrocarbons. Such gases injected into virgin or fracturedformations may tend to channel and may not be uniformly distributedthroughout the formation. In contrast, a gas injected into a pyrolyzedportion of a coal formation may readily and substantially uniformlycontact the carbon and/or hydrocarbons remaining in the formation. Inaddition, gases produced by heating the hydrocarbons may be transferreda significant distance within the heated portion of the formation with aminimal pressure loss. Such transfer of gases may be particularlyadvantageous, for example, in treating a steeply dipping coal formation.

[0547] Synthesis gas may be produced from a portion of a coal formation.The coal formation may be heated prior to synthesis gas generation toproduce a substantially uniform, relatively high permeability formation.In an embodiment, synthesis gas production may be commenced afterproduction of pyrolysis fluids has been substantially exhausted orbecomes uneconomical. Alternately, synthesis gas generation may becommenced before substantial exhaustion or uneconomical pyrolysis fluidproduction has been achieved if production of synthesis gas will be moreeconomically favorable. Formation temperatures will usually be higherthan pyrolysis temperatures during synthesis gas generation. Raising theformation temperature from pyrolysis temperatures to synthesis gasgeneration temperatures allows further utilization of heat applied tothe formation to pyrolyze the formation. While raising a temperature ofa formation from pyrolysis temperatures to synthesis gas temperatures,methane and/or H₂ may be produced from the formation.

[0548] Producing synthesis gas from a formation from which pyrolyzationfluids have been previously removed allows a synthesis gas to beproduced that includes mostly H₂, CO, water and/or CO₂. Producedsynthesis gas, in certain embodiments, may have substantially nohydrocarbon component unless a separate source hydrocarbon stream isintroduced into the formation with or in addition to the synthesis gasproducing fluid. Producing synthesis gas from a substantially uniform,relatively high permeability formation that was formed by slowly heatinga formation through pyrolysis temperatures may allow for easyintroduction of a synthesis gas generating fluid into the formation, andmay allow the synthesis gas generating fluid to contact a relativelylarge portion of the formation. The synthesis gas generating fluid cando so because the permeability of the formation has been increasedduring pyrolysis and/or because the surface area per volume in theformation has increased during pyrolysis. The relatively large surfacearea (e.g., “contact area”) in the post-pyrolysis formation tends toallow synthesis gas generating reactions to be substantially atequilibrium conditions for C, H₂, CO, water and CO₂. Reactions in whichmethane is formed may, however, not be at equilibrium because they arekinetically limited. The relatively high, substantially uniformformation permeability may allow production wells to be spaced fartherapart than production wells used during pyrolysis of the formation.

[0549] A temperature of at least a portion of a formation that is usedto generate synthesis gas may be raised to a synthesis gas generatingtemperature (e.g., between about 400° C. and about 1200° C.). In someembodiments composition of produced synthesis gas may be affected byformation temperature, by the temperature of the formation adjacent tosynthesis gas production wells, and/or by residence time of thesynthesis gas components. A relatively low synthesis gas generationtemperature may produce a synthesis gas having a high H₂ to CO ratio,but the produced synthesis gas may also include a large portion of othergases such as water, CO₂, and methane. A relatively high formationtemperature may produce a synthesis gas having a H₂ to CO ratio thatapproaches 1, and the stream may include mostly (and in some casessubstantially only) H₂ and CO. If the synthesis gas generating fluid issubstantially pure steam, then the H₂ to CO ratio may approach 1 atrelatively high temperatures. At a formation temperature of about 700°C., the formation may produce a synthesis gas with a H₂ to CO ratio ofabout 2 at a certain pressure. The composition of the synthesis gastends to depend on the nature of the synthesis gas generating fluid.

[0550] Synthesis gas generation is generally an endothermic process.Heat may be added to a portion of a formation during synthesis gasproduction to keep formation temperature at a desired synthesis gasgenerating temperature or above a minimum synthesis gas generatingtemperature. Heat may be added to the formation from heat sources, fromoxidation reactions within the portion, and/or from introducingsynthesis gas generating fluid into the formation at a highertemperature than the temperature of the formation.

[0551] An oxidant may be introduced into a portion of the formation withsynthesis gas generating fluid. The oxidant may exothermically reactwith carbon within the portion of the formation to heat the formation.Oxidation of carbon within a formation may allow a portion of aformation to be economically heated to relatively high synthesis gasgenerating temperatures. The oxidant may also be introduced into theformation without synthesis gas generating fluid to heat the portion.Using an oxidant, or an oxidant and heat sources, to heat the portion ofthe formation may be significantly more favorable than heating theportion of the formation with only the heat sources. The oxidant may be,but is not limited to, air, oxygen, or oxygen enriched air. The oxidantmay react with carbon in the formation to produce CO₂ and/or CO. The useof air, or oxygen enriched air (i.e., air with an oxygen content greaterthan 21% by volume), to generate heat within the formation may cause asignificant portion of N₂ to be present in produced synthesis gas.Temperatures in the formation may be maintained below temperaturesneeded to generate oxides of nitrogen (NO_(x)), so that little or noNO_(x) compounds may be present in produced synthesis gas.

[0552] A mixture of steam and oxygen, or steam and air, may besubstantially continuously injected into a formation. If injection ofsteam and oxygen is used for synthesis gas production, the oxygen may beproduced on site by electrolysis of water utilizing direct currentoutput of a fuel cell. H₂ produced by the electrolysis of water may beused as a fuel stream for the fuel cell. O₂ produced by the electrolysisof water may be injected into the hot formation to raise a temperatureof the formation.

[0553] Heat sources and/or production wells within a formation forpyrolyzing and producing pyrolysis fluids from the formation may beutilized for different purposes during synthesis gas production. A wellthat was used as a heat source or a production well during pyrolysis maybe used as an injection well to introduce synthesis gas producing fluidinto the formation. A well that was used as a heat source or aproduction well during pyrolysis may be used as a production well duringsynthesis gas generation. A well that was used as a heat source or aproduction well during pyrolysis may be used as a heat source to heatthe formation during synthesis gas generation. Synthesis gas productionwells may be spaced further apart than pyrolysis production wellsbecause of the relatively high, substantially uniform permeability ofthe formation. Synthesis gas production wells may be heated torelatively high temperatures so that a portion of the formation adjacentto the production well is at a temperature that will produce a desiredsynthesis gas composition. Comparatively, pyrolysis fluid productionwells may not be heated at all, or may only be heated to a temperaturethat will inhibit condensation of pyrolysis fluid within the productionwell.

[0554] Synthesis gas may be produced from a dipping formation from wellsused during pyrolysis of the formation. As shown in FIG. 4, synthesisgas production wells 206 may be located above and down dip from aninjection well 208. Hot synthesis gas producing fluid may be introducedinto injection well 208. Hot synthesis gas fluid that moves down dip maygenerate synthesis gas that is produced through synthesis gas productionwells 206. Synthesis gas generating fluid that moves up dip may generatesynthesis gas in a portion of the formation that is at synthesis gasgenerating temperatures. A portion of the synthesis gas generating fluidand generated synthesis gas that moves up dip above the portion of theformation at synthesis gas generating temperatures may heat adjacentformation. The synthesis gas generating fluid that moves up dip maycondense, heat adjacent portions of formation, and flow downwardstowards or into a portion of the formation at synthesis gas generatingtemperature. The synthesis gas generating fluid may then generateadditional synthesis gas.

[0555] Synthesis gas generating fluid may be any fluid capable ofgenerating H₂ and CO within a heated portion of a formation. Synthesisgas generating fluid may include water, O₂, air, CO₂, hydrocarbonfluids, or combinations thereof. Water may be introduced into aformation as a liquid or as steam. Water may react with carbon in aformation to produce H₂, CO, and CO₂. CO₂ may react with hot carbon toform CO. Air and O₂ may be oxidants that react with carbon in aformation to generate heat and form CO₂, CO, and other compounds.Hydrocarbon fluids may react within a formation to form H₂, CO, CO₂,H₂O, coke, methane and/or other light hydrocarbons. Introducing lowcarbon number hydrocarbons (i.e., compounds with carbon numbers lessthan 5) may produce additional H₂ within the formation. Adding highercarbon number hydrocarbons to the formation may increase an energycontent of generated synthesis gas by having a significant methane andother low carbon number compounds fraction within the synthesis gas.

[0556] Water provided as a synthesis gas generating fluid may be derivedfrom numerous different sources. Water may be produced during apyrolysis stage of treating a formation. The water may include someentrained hydrocarbon fluids. Such fluid may be used as synthesis gasgenerating fluid. Water that includes hydrocarbons may advantageouslygenerate additional H₂ when used as a synthesis gas generating fluid.Water produced from water pumps that inhibit water flow into a portionof formation being subjected to an in situ conversion process mayprovide water for synthesis gas generation. A low rank kerogen resourceor hydrocarbons having a relatively high water content (i.e. greaterthan about 20% H₂O by weight) may generate a large amount of waterand/or CO₂ if subjected to an in situ conversion process. The water andCO₂ produced by subjecting a low rank kerogen resource to an in situconversion process may be used as a synthesis gas generating fluid.

[0557] Reactions involved in the formation of synthesis gas may include,but are not limited to:

C+H₂O←→H₂+CO  (1)

C+2H₂O←→2H₂+CO₂  (2)

C+CO₂←→2CO  (3)

[0558] Thermodynamics allows the following reactions to proceed:

2C+2H₂O←→CH₄+CO₂  (4)

C+2H₂←→CH₄  (5)

[0559] However, kinetics of the reactions are slow in certainembodiments so that relatively low amounts of methane are formed atformation conditions from Reactions (4) and (5).

[0560] In the presence of oxygen, the following reaction may take placeto generate carbon dioxide and heat:

C+O₂→CO₂  (6)

[0561] Equilibrium gas phase compositions of coal in contact with steammay provide an indication of the compositions of components produced ina formation during synthesis gas generation. Equilibrium compositiondata for H₂, carbon monoxide, and carbon dioxide may be used todetermine appropriate operating conditions such as temperature that maybe used to produce a synthesis gas having a selected composition.Equilibrium conditions may be approached within a formation due to ahigh, substantially uniform permeability of the formation. Compositiondata obtained from synthesis gas production may in many instancesdeviate by less than 10% from equilibrium values.

[0562] In one embodiment, a composition of the produced synthesis gascan be changed by injecting additional components into the formationalong with steam. Carbon dioxide may be provided in the synthesis gasgenerating fluid to substantially inhibit production of carbon dioxideproduced from the formation during synthesis gas generation. The carbondioxide may shift the equilibrium of reaction (2) to the left, thusreducing the amount of carbon dioxide generated from formation carbon.The carbon dioxide may also react with carbon in the formation togenerate carbon monoxide. Carbon dioxide may be separated from thesynthesis gas and may be re-injected into the formation with thesynthesis gas generating fluid. Addition of carbon dioxide in thesynthesis gas generating fluid may, however, reduce the production ofhydrogen.

[0563]FIG. 29 depicts a schematic diagram of use of water recovered frompyrolysis fluid production being used to generate synthesis gas. Heatsource 801 with electric heater 803 produces pyrolysis fluid 807 fromfirst section 805 of the formation. Produced pyrolysis fluid 807 may besent to separator 809. Separator 809 may include a number of individualseparation units and processing units that produce aqueous stream 811,vapor stream 813, and hydrocarbon condensate stream 815. Aqueous stream811 from the separator 809 may be combined with synthesis gas generatingfluid 818 to form synthesis gas generating fluid 821. Synthesis gasgenerating fluid 821 may be provided to injection well 817 andintroduced to second portion 819 of the formation. Synthesis gas 823 maybe produced from synthesis gas production well 825.

[0564]FIG. 30 depicts a schematic diagram of an embodiment of a systemfor synthesis gas production in which carbon dioxide from producedsynthesis gas is injected into a formation. Synthesis gas 830 may beproduced from formation 832 through production well 834. Gas separationunit 836 may separate a portion of carbon dioxide from the synthesis gas830 to produce CO₂ stream 838 and remaining synthesis gas stream 840.The CO₂ stream 838 may be mixed with synthesis gas producing fluidstream 842 that is introduced into the formation 832 through injectionwell 837, and/or the CO₂ may be separately introduced into theformation. This may limit conversion of carbon within the formation toCO₂ and/or may increase an amount of CO generated within the formation.

[0565] Synthesis gas generating fluid may be introduced into a formationin a variety of different ways. Steam may be injected into a heated coalformation at a lowermost portion of the heated formation. Alternatively,in a steeply dipping formation, steam may be injected up dip withsynthesis gas production down dip. The injected steam may pass throughthe remaining coal formation to a production well. In addition,endothermic heat of reaction may be provided to the formation with heatsources disposed along a path of the injected steam. In alternateembodiments, steam may be injected at a plurality of locations along thecoal formation to increase penetration of the steam throughout theformation. A line drive pattern of locations may also be utilized. Theline drive pattern may include alternating rows of steam injection wellsand synthesis gas production wells.

[0566] At relatively low pressures, and temperatures below about 400°C., synthesis gas reactions are relatively slow. At relatively lowpressures, and temperatures between about 400° C. and about 700° C.,Reaction (2) tends to be the predominate reaction and the synthesis gascomposition is primarily hydrogen and carbon dioxide. At relatively lowpressures, and temperatures greater than about 700° C., Reaction (1)tends to be the predominate reaction and the synthesis gas compositionis primarily hydrogen and carbon monoxide.

[0567] Advantages of a lower temperature synthesis gas reaction mayinclude lower heat requirements, cheaper metallurgy and less endothermicreactions (especially when methane formation takes place). An advantageof a higher temperature synthesis gas reaction is that hydrogen andcarbon monoxide may be used as feedstock for other processes (e.g.,Fischer-Tropsch processes).

[0568] A pressure of the coal formation may be maintained at relativelyhigh pressures during synthesis gas production. The pressure may rangefrom atmospheric pressure to a lithostatic pressure of the formation.Higher formation pressures may allow generation of electricity bypassing produced synthesis gas through a turbine. Higher formationpressures may allow for smaller collection conduits to transportproduced synthesis gas, and reduced downstream compression requirementson the surface.

[0569] In some embodiments, synthesis gas may be produced from a portionof a formation in a substantially continuous manner. The portion may beheated to a desired synthesis gas generating temperature. A synthesisgas generating fluid may be introduced into the portion. Heat may beadded to, or generated within, the portion of the formation duringintroduction of the synthesis gas generating fluid to the portion. Theadded heat compensates for the loss of heat due to the endothermicsynthesis gas reactions as well as heat losses to the top and bottomlayers, etc. In other embodiments, synthesis gas may be produced in asubstantially batch manner. The portion of the formation may be heated,or heat may be generated within the portion, to raise a temperature ofthe portion to a high synthesis gas generating temperature. Synthesisgas generating fluid may then be added to the portion until generationof synthesis gas reduces the temperature of the formation below atemperature that produces a desired synthesis gas composition.Introduction of the synthesis gas generating fluid may then be stopped.The cycle may be repeated by reheating the portion of the formation tothe high synthesis gas generating temperature and adding synthesis gasgenerating fluid after obtaining the high synthesis gas generatingtemperature. Composition of generated synthesis gas may be monitored todetermine when addition of synthesis gas generating fluid to theformation should be stopped.

[0570]FIG. 31 illustrates a schematic of an embodiment of a continuoussynthesis gas production system. FIG. 31 includes a formation with heatinjection wellbore 850 and heat injection wellbore 852. The wellboresmay be members of a larger pattern of wellbores placed throughout aportion of the formation. A portion of a formation may be heated tosynthesis gas generating temperatures by heating the formation with heatsources, by injecting an oxidizing fluid, or by a combination thereof.Oxidizing fluid 854, such as air or oxygen, and synthesis gas generatingfluid 856, such as steam, may be injected into wellbore 850. In oneembodiment, the ratio of oxygen to steam may be approximately 1:2 toapproximately 1:10, or approximately 1:3 to approximately 1:7 (e.g.,about 1:4).

[0571] In situ combustion of hydrocarbons may heat region 858 of theformation between wellbores 850 and 852. Injection of the oxidizingfluid may heat region 858 to a particular temperature range, forexample, between about 600° C. and about 700° C. The temperature mayvary, however, depending on a desired composition of the synthesis gas.An advantage of the continuous production method may be that thetemperature across region 858 may be substantially uniform andsubstantially constant with time once the formation has reachedsubstantial thermal equilibrium. Continuous production may alsoeliminate a need for use of valves to reverse injection directions on asubstantially frequent basis. Further, continuous production may reducetemperatures near the injections wells due to endothermic cooling fromthe synthesis gas reaction that may occur in the same region asoxidative heating. The substantially constant temperature may allow forcontrol of synthesis gas composition. Produced synthesis gas 860 mayexit continuously from wellbore 852.

[0572] In an embodiment, it may be desirable to use oxygen rather thanair as oxidizing fluid 854 in continuous production. If air is used,nitrogen may need to be separated from the synthesis gas. The use ofoxygen as oxidizing fluid 854 may increase a cost of production due tothe cost of obtaining substantially pure oxygen. The cryogenic nitrogenby-product obtained from an air separation plant used to produce therequired oxygen may, however, be used in a heat exchanger to condensehydrocarbons from a hot vapor stream produced during pyrolysis ofhydrocarbons. The pure nitrogen may also be used for ammonia production.

[0573]FIG. 32 illustrates a schematic of an embodiment of a batchproduction of synthesis gas in a coal formation. Wellbore 870 andwellbore 872 may be located within a portion of the formation. Thewellbores may be members of a larger pattern of wellbores throughout theportion of the formation. Oxidizing fluid 874, such as air or oxygen,may be injected into wellbore 870. Oxidation of hydrocarbons may heatregion 876 of a formation between wellbores 870 and 872. Injection ofair or oxygen may continue until an average temperature of region 876 isat a desired temperature (e.g., between about 900° C. and about 1000°C.). Higher or lower temperatures may also be developed. A temperaturegradient may be formed in region 876 between wellbore 870 and wellbore872. The highest temperature of the gradient may be located proximate tothe injection wellbore 870.

[0574] When a desired temperature has been reached, or when oxidizingfluid has been injected for a desired period of time, oxidizing fluidinjection may be lessened and/or ceased. A synthesis gas generatingfluid 877, such as steam or water, may be injected into the injectionwellbore 872 to produce synthesis gas. A back pressure of the injectedsteam or water in the injection wellbore may force the synthesis gasproduced and un-reacted steam across region 876. A decrease in averagetemperature of region 876 caused by the endothermic synthesis gasreaction may be partially offset by the temperature gradient in region876 in a direction indicated by arrow 878. Product stream 880 may beproduced through heat source wellbore 870. If the composition of theproduct deviates substantially from a desired composition, then steaminjection may cease, and air or oxygen injection may be reinitiated.

[0575] In one embodiment, synthesis gas of a selected composition may beproduced by blending synthesis gas produced from different portions ofthe formation. A first portion of a formation may be heated by one ormore heat sources to a first temperature sufficient to allow generationof synthesis gas having a H₂ to carbon monoxide ratio of less than theselected H₂ to carbon monoxide ratio (e.g., about 1 or 2). A firstsynthesis gas generating fluid may be provided to the first portion togenerate a first synthesis gas. The first synthesis gas may be producedfrom the formation. A second portion of the formation may be heated byone or more heat sources to a second temperature sufficient to allowgeneration of synthesis gas having a H₂ to carbon monoxide ratio ofgreater than the selected H₂ to carbon monoxide ratio (e.g., a ratio of3 or more). A second synthesis gas generating fluid may be provided tothe second portion to generate a second synthesis gas. The secondsynthesis gas may be produced from the formation. The first synthesisgas may be blended with the second synthesis gas to produce a blendsynthesis gas having a desired H₂ to carbon monoxide ratio.

[0576] The first temperature may be substantially different than thesecond temperature. Alternatively, the first and second temperatures maybe approximately the same temperature. For example, a temperaturesufficient to allow generation of synthesis gas having differentcompositions may vary depending on compositions of the first and secondportions and/or prior pyrolysis of hydrocarbons within the first andsecond portions. The first synthesis gas generating fluid may havesubstantially the same composition as the second synthesis gasgenerating fluid. Alternatively, the first synthesis gas generatingfluid may have a different composition than the second synthesis gasgenerating fluid. Appropriate first and second synthesis generatingfluids may vary depending upon, for example, temperatures of the firstand second portions, compositions of the first and second portions, andprior pyrolysis of hydrocarbons within the first and second portions.

[0577] In addition, synthesis gas having a selected ratio of H₂ tocarbon monoxide may be obtained by controlling the temperature of theformation. In one embodiment, the temperature of an entire portion orsection of the formation may be controlled to yield synthesis gas with aselected ratio. Alternatively, the temperature in or proximate to asynthesis gas production well may be controlled to yield synthesis gaswith the selected ratio.

[0578] In one embodiment, synthesis gas having a selected ratio of H₂ tocarbon monoxide may be obtained by treating produced synthesis gas atthe surface. First, the temperature of the formation may be controlledto yield synthesis gas with a ratio different than a selected ratio. Forexample, the formation may be maintained at a relatively hightemperature to generate a synthesis gas with a relatively low H₂ tocarbon monoxide ratio (e.g., the ratio may approach 1 under certainconditions). Some or all of the produced synthesis gas may then beprovided to a shift reactor (shift process) at the surface. Carbonmonoxide reacts with water in the shift process to produce H₂ and carbondioxide. Therefore, the shift process increases the H₂ to carbonmonoxide ratio. The carbon dioxide may then be separated to obtain asynthesis gas having a selected H₂ to carbon monoxide ratio.

[0579] In one embodiment, produced synthesis gas 918 may be used forproduction of energy. In FIG. 33, treated gases 920 may be routed fromtreatment section 900 to energy generation unit 902 for extraction ofuseful energy. Energy may be extracted from the combustible gasesgenerally by oxidizing the gases to produce heat and converting aportion of the heat into mechanical and/or electrical energy.Alternatively, energy generation unit 902 may include a fuel cell thatproduces electrical energy. In addition, energy generation unit 902 mayinclude, for example, a molten carbonate fuel cell or another type offuel cell, a turbine, a boiler firebox, or a down hole gas heater.Produced electrical energy 904 may be supplied to power grid 906. Aportion of the produced electricity 908 may be used to supply energy toelectrical heating elements 910 that heat formation 912.

[0580] In one embodiment, energy generation unit 902 may be a boilerfirebox. A firebox may include a small refractory-lined chamber, builtwholly or partly in the wall of a kiln, for combustion of fuel. Air oroxygen 914 may be supplied to energy generation unit 902 to oxidize theproduced synthesis gas. Water 916 produced by oxidation of the synthesisgas may be recycled to the formation to produce additional synthesisgas.

[0581] The produced synthesis gas may also be used as a fuel in downhole gas heaters. Down hole gas heaters, such as a flameless combustoras disclosed herein, may be configured to heat a coal formation. In thismanner, a thermal conduction process may be substantially self-reliantand/or may substantially reduce or eliminate a need for electricity.Because flameless combustors may have a thermal efficiency approaching90%, an amount of carbon dioxide released to the environment may be lessthan an amount of carbon dioxide released to the environment from aprocess using fossil-fuel generated electricity to heat the coalformation.

[0582] Carbon dioxide may be produced by both pyrolysis and synthesisgas generation. Carbon dioxide may also be produced by energy generationprocesses and/or combustion processes. Net release of carbon dioxide tothe atmosphere from an in situ conversion process for coal may bereduced by utilizing the produced carbon dioxide and/or by storingcarbon dioxide within the formation. For example, a portion of carbondioxide produced from the formation may be utilized as a flooding agentor as a feedstock for producing chemicals.

[0583] In one embodiment, the energy generation process may produce areduced amount of emissions by sequestering carbon dioxide producedduring extraction of useful energy. For example, emissions from anenergy generation process may be reduced by storing an amount of carbondioxide within a coal formation. The amount of stored carbon dioxide maybe approximately equivalent to that in an exit stream from theformation.

[0584]FIG. 33 illustrates a reduced emission energy process. Carbondioxide 928 produced by energy generation unit 902 may be separated fromfluids exiting the energy generation unit. Carbon dioxide may beseparated from H₂ at high temperatures by using a hot palladium filmsupported on porous stainless steel or a ceramic substrate, or hightemperature pressure swing adsorption. The carbon dioxide may besequestered in spent coal formation 922, injected into oil producingfields 924 for enhanced oil recovery by improving mobility andproduction of oil in such fields, sequestered into a deep coal formation926 containing methane by adsorption and subsequent desorption ofmethane, or re-injected 928 into a section of the formation through asynthesis gas production well to produce carbon monoxide. Carbon dioxideleaving the energy generation unit may be sequestered in a dewateredcoal bed methane reservoir. The water for synthesis gas generation maycome from dewatering a coal bed methane reservoir. Additional methanecan also be produced by alternating carbon dioxide and nitrogen. Anexample of a method for sequestering carbon dioxide is illustrated inU.S. Pat. No. 5,566,756 to Chaback et al., which is incorporated byreference as if fully set forth herein. Additional energy may beutilized by removing heat from the carbon dioxide stream leaving theenergy generation unit.

[0585] In one embodiment, it may be desirable to cool a hot spentformation before sequestration of carbon dioxide. For example, a higherquantity of carbon dioxide may be adsorbed in a coal formation at lowertemperatures. In addition, cooling a formation may strengthen aformation. The spent formation may be cooled by introducing water intothe formation. The steam produced may be removed from the formation. Thegenerated steam may be used for any desired process. For example, thesteam may be provided to an adjacent portion of a formation to heat theadjacent portion or to generate synthesis gas.

[0586] In one embodiment, a spent coal formation may be mined. The minedmaterial may in some embodiments be used for metallurgical purposes suchas a fuel for generating high temperatures during production of steel.Pyrolysis of a coal formation may substantially increase a rank of thecoal. After pyrolysis, the coal may be substantially transformed to acoal having characteristics of anthracite. A spent coal formation mayhave a thickness of 30 m or more. Anthracite coal seams, which aretypically mined for metallurgical uses, may be only about one meter inthickness.

[0587]FIG. 34 illustrates an embodiment in which fluid produced frompyrolysis may be separated into a fuel cell feed stream and fed into afuel cell to produce electricity. The embodiment may include carboncontaining formation 940 with producing well 942 configured to producesynthesis gas and heater well 944 with electric heater 946 configured toproduced pyrolysis fluid 948. In one embodiment, pyrolysis fluid mayinclude H₂ and hydrocarbons with carbon numbers less than 5. Pyrolysisfluid 948 produced from heater well 944 may be fed to gas membraneseparation system 950 to separate H₂ and hydrocarbons with carbonnumbers less than 5. Fuel cell feed stream 952, which may besubstantially composed of H₂, may be fed into fuel cell 954. Air feedstream 956 may be fed into fuel cell 954. Nitrogen stream 958 may bevented from fuel cell 954. Electricity 960 produced from the fuel cellmay be routed to a power grid. Electricity 962 may also be used to powerelectric heaters 946 in heater wells 944. Carbon dioxide 965 may beinjected into formation 940.

[0588] Hydrocarbons having carbon numbers of 4, 3, and 1 typically havefairly high market values. Separation and selling of these hydrocarbonsmay be desirable. Typically ethane may not be sufficiently valuable toseparate and sell in some markets. Ethane may be sent as part of a fuelstream to a fuel cell or ethane may be used as a hydrocarbon fluidcomponent of a synthesis gas generating fluid. Ethane may also be usedas a feedstock to produce ethene. In some markets, there may be nomarket for any hydrocarbons having carbon numbers less than 5. In such asituation, all of the hydrocarbon gases produced during pyrolysis may besent to fuel cells or be used as hydrocarbon fluid components of asynthesis gas generating fluid.

[0589] Pyrolysis fluid 964, which may be substantially composed ofhydrocarbons with carbon numbers less than 5, may be injected intoformation 940. When the hydrocarbons contact the formation, hydrocarbonsmay crack within the formation to produce methane, H₂ coke, and olefinssuch as ethene and propylene. In one embodiment, the production ofolefins may be increased by heating the temperature of the formation tothe upper end of the pyrolysis temperature range and by injectinghydrocarbon fluid at a relatively high rate. In this manner, residencetime of the hydrocarbons in the formation may be reduced anddehydrogenated hydrocarbons may tend to form olefins rather thancracking to form H₂ and coke. Olefin production may also be increased byreducing formation pressure.

[0590] In one embodiment, electric heater 946 may be a flamelessdistributed combustor. At least a portion of H₂ produced from theformation may be used as fuel for the flameless distributed combustor.

[0591] In addition, in some embodiments, heater well 944 may heat theformation to a synthesis gas generating temperature range. Pyrolysisfluid 964, which may be substantially composed of hydrocarbons withcarbon numbers less than 5, may be injected into the formation 940. Whenthe hydrocarbons contact the formation, the hydrocarbons may crackwithin the formation to produce methane, H₂, and coke.

[0592]FIG. 35 depicts an embodiment of a synthesis gas generatingprocess from coal formation 976 with flameless distributed combustor996. Synthesis gas 980 produced from production well 978 may be fed intogas separation plant 984 where carbon dioxide 986 may be separated fromsynthesis gas 980. First portion 990 of carbon dioxide may be routed toa formation for sequestration. Second portion 992 of carbon dioxide mayalso be injected into the formation with synthesis gas generating fluid.Portion 993 of synthesis gas 988 may be fed to heater well 994 forcombustion in distributed burner 996 to produce heat for the formation.Portion 998 of synthesis gas 988 may be fed to fuel cell 1000 for theproduction of electricity. Electricity 1002 may be routed to a powergrid. Steam 1004 produced in the fuel cell and steam 1006 produced fromcombustion in the distributed burner may be fed to the formation forgeneration of synthesis gas.

[0593] In one embodiment, carbon dioxide generated with pyrolysis fluidsas described herein may be sequestered in a coal formation. FIG. 36illustrates in situ pyrolysis in coal formation 1020. Heater well 1022with electric heater 1024 may be disposed in formation 1020. Pyrolysisfluids 1026 may be produced from formation 1020 and fed into gasseparation unit 1028 where carbon dioxide 1030 may be separated frompyrolysis fluids 1032. Portion 1034 of carbon dioxide 1030 may be storedin formation 1036. The carbon dioxide may be sequestered in spent coalformation 1038, injected into oil producing fields 1040 for enhanced oilrecovery, or sequestered into coal bed 1042. Alternatively, carbondioxide may also be re-injected 1044 into a section of formation 1020through a synthesis gas production well to produce carbon monoxide. Atleast a portion of electricity 1035 may be used to power one or moreelectric heaters.

[0594] In one embodiment, fluid produced from pyrolysis of at least somehydrocarbons in a formation may be fed into a reformer to producesynthesis gas. The synthesis gas may be fed into a fuel cell to produceelectricity. In addition, carbon dioxide generated by the fuel cell maybe sequestered to reduce an amount of emissions generated by theprocess.

[0595] As shown in FIG. 37, heater well 1060 may be located within coalformation 1062. Additional heater wells may also be located within theformation. Heater well 1060 may include electric heater 1064. Pyrolysisfluid 1066 produced from the formation may be fed to a reformer, such assteam reformer 1068, to produce synthesis gas 1070. A portion of thepyrolysis products may be used as fuel in the reformer. Steam reformer1068 may include a catalyst material that promotes the reformingreaction and a burner to supply heat for the endothermic reformingreaction. A steam source may be connected to the reformer section toprovide steam for the reforming reaction. The burner may operate attemperatures well above that required by the reforming reaction and wellabove the operating temperatures of fuel cells. As such, it may bedesirable to operate the burner as a separate unit independent of thefuel cell.

[0596] Alternatively, a reformer may include multiple tubes that may bemade of refractory metal alloys. Each tube may include a packed granularor pelletized material having a reforming catalyst as a surface coating.A diameter of the tubes may vary from between about 9 cm and about 16cm, and the heated length of the tube may normally be between about 6 mand about 12 m. A combustion zone may be provided external to the tubes,and may be formed in the burner. A surface temperature of the tubes maybe maintained by the burner at a temperature of about 900° C. to ensurethat the hydrocarbon fluid flowing inside the tube is properly catalyzedwith steam at a temperature between about 500° C. and about 700° C. Atraditional tube reformer may rely upon conduction and convection heattransfer within the tube to distribute heat for reforming.

[0597] In addition, hydrocarbon fluids, such as pyrolysis fluids, may bepre-processed prior to being fed to a reformer. The reformer may beconfigured to transform the pyrolysis fluids into simpler reactantsprior to introduction to a fuel cell. For example, pyrolysis fluids maybe pre-processed in a desulfurization unit. Subsequent topre-processing, the pyrolysis fluids may be provided to a reformer and ashift reactor to produce a suitable fuel stock for a H₂ fueled fuelcell.

[0598] The synthesis gas produced by the reformer may include any of thecomponents described above, such as methane. The produced synthesis gas1070 may be fed to fuel cell 1072. A portion of electricity 1074produced by the fuel cell may be sent to a power grid. In addition, aportion of electricity 1076 may be used to power electric heater 1064.Carbon dioxide 1078 exiting the fuel cell may be routed to sequestrationarea 1080.

[0599] Alternatively, in one embodiment, pyrolysis fluids 1066 producedfrom the formation may be fed to reformer 1068 that produces carbondioxide stream 1082 and H₂ stream 1070. For example, the reformer mayinclude a flameless distributed combustor for a core, and a membrane.The membrane may allow only H₂ to pass through the membrane resulting inseparation of the H₂ and carbon dioxide. The carbon dioxide may berouted to sequestration area 1080.

[0600] Synthesis gas produced from a formation may be converted toheavier condensable hydrocarbons. For example, a Fischer-Tropschhydrocarbon synthesis process may be used for conversion of synthesisgas. A Fischer-Tropsch process may include converting synthesis gas tohydrocarbons. The process may use elevated temperatures, normal orelevated pressures, and a catalyst, such as magnetic iron oxide or acobalt catalyst. Products produced from a Fischer-Tropsch process mayinclude hydrocarbons having a broad molecular weight distribution andmay include branched and unbranched paraffins. Products from aFischer-Tropsch process may also include considerable quantities ofolefins and oxygen-containing organic compounds. An example of aFischer-Tropsch reaction may be illustrated by the following:

(n+2)CO+(2n+5)H₂←→CH₃(—CH₂—)n CH₃+(n+2)H₂O  (7)

[0601] A hydrogen to carbon monoxide ratio for synthesis gas used as afeed gas for a Fischer-Tropsch reaction may be about 2:1. In certainembodiments the ratio may range from approximately 1.8:1 to 2.2:1.Higher or lower ratios may be accommodated by certain Fischer-Tropschsystems.

[0602]FIG. 38 illustrates a flowchart of a Fischer-Tropsch process thatuses synthesis gas produced from a coal formation as a feed stream. Hotformation 1090 may be used to produce synthesis gas having a H₂ to COratio of approximately 2:1. The proper ratio may be produced byoperating synthesis production wells at approximately 700° C., or byblending synthesis gas produced from different sections of formation toobtain a synthesis gas having approximately a 2:1 H₂ to CO ratio.Synthesis gas generating fluid 1092 may be fed into the hot formation1090 to generate synthesis gas. H₂ and CO may be separated from thesynthesis gas produced from the hot formation 1090 to form feed stream1094. Feed stream 1094 may be sent to Fischer-Tropsch plant 1096. Feedstream 1094 may supplement or replace synthesis gas 1098 produced fromcatalytic methane reformer 1100.

[0603] Fischer-Tropsch plant 1096 may produce wax feed stream 1102. TheFischer-Tropsch synthesis process that produces wax feed stream 1102 isan exothermic process. Steam 1104 may be generated during theFischer-Tropsch process. Steam 1104 may be used as a portion ofsynthesis gas generating fluid 1092.

[0604] Wax feed stream 1102 produced from Fischer-Tropsch plant 1096 maybe sent to hydrocracker 1106. The hydrocracker may produce productstream 1108. The product stream may include diesel, jet fuel, and/ornaphtha products. Examples of methods for conversion of synthesis gas tohydrocarbons in a Fischer-Tropsch process are illustrated in U.S. Pat.No. 4,096,163 to Chang et al., U.S. Pat. No. 6,085,512 to Agee et al.,and U.S. Pat. No. 6,172,124 to Wolflick et al., which are incorporatedby reference as if fully set forth herein.

[0605]FIG. 39 depicts an embodiment of in situ synthesis gas productionintegrated with a Shell Middle Distillates Synthesis (SMDS)Fischer-Tropsch and wax cracking process. An example of a SMDS processis illustrated in U.S. Pat. No. 4,594,468 to Minderhoud, and isincorporated by reference as if fully set forth herein. A middledistillates hydrocarbon mixture may also be produced from producedsynthesis gas using the SMDS process as illustrated in FIG. 39. Middledistillates may designate hydrocarbon mixtures with a boiling pointrange that may correspond substantially with that of kerosene and gasoil fractions obtained in a conventional atmospheric distillation ofcrude oil material. The middle distillate boiling point range mayinclude temperatures between about 150° C. and about 360° C., with afractions boiling point between about 200° C. and about 360° C., and maybe referred to as gas oil. FIG. 39 depicts synthesis gas 1120, having aH₂ to carbon monoxide ratio of about 2:1, that may exit production well1128 and may be fed into SMDS plant 1122. In certain embodiments theratio may range from approximately 1.8:1 to 2.2:1. Products of the SMDSplant include organic liquid product 1124 and steam 1126. Steam 1126 maybe supplied to injection wells 1127. In this manner, steam may be usedas a feed for synthesis gas production. Hydrocarbon vapors may in somecircumstances be added to the steam.

[0606]FIG. 40 depicts an embodiment of in situ synthesis gas productionintegrated with a catalytic methanation process. For example, synthesisgas 1140 exiting production well 1142 may be supplied to catalyticmethanation plant 1144. In some embodiments, it may be desirable for thecomposition of produced synthesis gas, which may be used as a feed gasfor a catalytic methanation process, to have a H₂ to carbon monoxideratio of about three to one. Methane 1146 may be produced by catalyticmethanation plant 1144. Steam 1148 produced by plant 1144 may besupplied to injection well 1141 for production of synthesis gas.Examples of a catalytic methanation process are illustrated in U.S. Pat.No. 3,992,148 to Child, U.S. Pat. No. 4,130,575 to Jom et al., and U.S.Pat. No. 4,133,825 to Stroud et al., which are incorporated by referenceas if fully set forth herein.

[0607] The synthesis gas produced may also be used as a feed for aprocess for production of methanol. Examples of processes for productionof methanol are illustrated in U.S. Pat. No. 4,407,973 to van Dijk etal., U.S. Pat. No. 4,927,857 to McShea, III et al., and U.S. Pat. No.4,994,093 to Wetzel et al., which are incorporated by reference as iffully set forth herein. The produced synthesis gas may also be used as afeed gas for a process that may convert synthesis gas to gasoline and aprocess that may convert synthesis gas to diesel fuel. Examples ofprocess for producing engine fuels are illustrated in U.S. Pat. No.4,076,761 to Chang et al., U.S. Pat. No. 4,138,442 to Chang et al., andU.S. Pat. No. 4,605,680 to Beuther et al., which are incorporated byreference as if fully set forth herein.

[0608] In one embodiment, produced synthesis gas may be used as a feedgas for production of ammonia and urea as illustrated by FIGS. 41 and42. Ammonia may be synthesized by the Haber-Bosch process, whichinvolves synthesis directly from N₂ and H₂ according to the reaction:

N₂+3H₂←→2NH₃  (8)

[0609] The N₂ and H₂ may be combined, compressed to high pressure (e.g.,from about 80 bars to about 220 bars) and heated to a relatively hightemperature. The reaction mixture may be passed over a catalyst composedsubstantially of iron, where ammonia production may occur. Duringammonia synthesis, the reactants (i.e., N₂ and H₂) and the product(i.e., ammonia) may be in equilibrium. In this manner, the total amountof ammonia produced may be increased by shifting the equilibrium towardsproduct formation. Equilibrium may be shifted to product formation byremoving ammonia from the reaction mixture as it is produced.

[0610] Removal of the ammonia may be accomplished by cooling the gasmixture to a temperature between about (−5)° C. to about 25° C. In thistemperature range, a two-phase mixture may be formed with ammonia in theliquid phase and N₂ and H₂ in the gas phase. The ammonia may beseparated from other components of the mixture. The nitrogen andhydrogen may be subsequently reheated to the operating temperature forammonia conversion and passed through the reactor again.

[0611] Urea may be prepared by introducing ammonia and carbon dioxideinto a reactor at a suitable pressure (e.g., from about 125 barsabsolute to about 350 bars absolute) and at a suitable temperature(e.g., from about 160° C. to about 250° C.). Ammonium carbamate may beformed according to the following reaction:

2NH₃+CO₂→NH₂(CO₂) NH₄  (9)

[0612] Urea may be subsequently formed by dehydrating the ammoniumcarbamate according to the following equilibrium reaction:

NH₂(CO₂) NH₄←→NH₂(CO)NH₂+H₂O  (10)

[0613] The degree to which the ammonia conversion takes place may dependon, for example, the temperature and the amount of excess ammonia. Thesolution obtained as the reaction product may substantially includeurea, water, ammonium carbamate and unbound ammonia. The ammoniumcarbamate and the ammonia may need to be removed from the solution. Onceremoved, they may be returned to the reactor. The reactor may includeseparate zones for the formation of ammonium carbamate and urea.However, these zones may also be combined into one piece of equipment.

[0614] According to one embodiment, a high pressure urea plant mayoperate such that the decomposition of the ammonium carbamate that hasnot been converted into urea and the expulsion of the excess ammonia maybe conducted at a pressure between 15 bars absolute and 100 barsabsolute. This may be considerably lower than the pressure in the ureasynthesis reactor. The synthesis reactor may be operated at atemperature of about 180° C. to about 210° C. and at a pressure of about180 bars absolute to about 300 bars absolute. Ammonia and carbon dioxidemay be directly fed to the urea reactor. The NH₃/CO₂ molar ratio (N/Cmolar ratio) in the urea synthesis may generally be between about 3 andabout 5. The unconverted reactants may be recycled to the urea synthesisreactor following expansion, dissociation, and/or condensation.

[0615] In one embodiment, an ammonia feed stream having a selected ratioof H₂ to N₂ may be generated from a formation using enriched air. Asynthesis gas generating fluid and an enriched air stream may beprovided to the formation. The composition of the enriched air may beselected to generate synthesis gas having the selected ratio of H₂ toN₂. In one embodiment, the temperature of the formation may becontrolled to generate synthesis gas having the selected ratio.

[0616] In one embodiment, the H₂ to N₂ ratio of the feed stream providedto the ammonia synthesis process may be approximately 3:1. In otherembodiments, the ratio may range from approximately 2.8:1 to 3.2:1. Anammonia synthesis feed stream having a selected H₂ to N₂ ratio may beobtained by blending feed streams produced from different portions ofthe formation.

[0617] In one embodiment, ammonia from the ammonia synthesis process maybe provided to a urea synthesis process to generate urea. Ammoniaproduced during pyrolysis may be added to the ammonia generated from theammonia synthesis process. In another embodiment, ammonia producedduring hydrotreating may be added to the ammonia generated from theammonia synthesis process. Some of the carbon monoxide in the synthesisgas may be converted to carbon dioxide in a shift process. The carbondioxide from the shift process may be fed to the urea synthesis process.Carbon dioxide generated from treatment of the formation may also befed, in some instances, to the urea synthesis process.

[0618]FIG. 41 illustrates an embodiment of a method for production ofammonia and urea from synthesis gas using membrane-enriched air.Enriched air 1170 and steam, or water, 1172 may be fed into hot carboncontaining formation 1174 to produce synthesis gas 1176 in a wetoxidation mode as described herein.

[0619] In certain embodiments, enriched air 1170 is blended from air andoxygen streams such that the nitrogen to hydrogen ratio in the producedsynthesis gas is about 1:3. The synthesis gas may be at a correct ratioof nitrogen and hydrogen to form ammonia. For example, it has beencalculated that for a formation temperature of 700° C. and a pressure of3 bar absolute, and with 13,231 tons/day of char that will be convertedinto synthesis gas, one could inject 14.7 kilotons/day of air, 6.2kilotons/day of oxygen, and 21.2 kilotons/day of steam. This wouldresult in production of 2 billion cubic feet/day of synthesis gasincluding 5689 tons/day of steam, 16,778 tons/day of carbon monoxide,1406 tons/day of hydrogen, 18,689 tons/day of carbon dioxide, 1258tons/day of methane, and 11,398 tons/day of nitrogen. After a shiftreaction (to shift the carbon monoxide to carbon dioxide, and to produceadditional hydrogen), the carbon dioxide may be removed, the productstream may be methanated (to remove residual carbon monoxide), and thenone can theoretically produce 13,840 tons/day of ammonia and 1258tons/day of methane. This calculation includes the products producedfrom Reactions (4) and (5) above.

[0620] Enriched air may be produced from a membrane separation unit.Membrane separation of air may be primarily a physical process. Basedupon specific characteristics of each molecule, such as size andpermeation rate, the molecules in air may be separated to formsubstantially pure forms of nitrogen, oxygen, or combinations thereof.

[0621] In one embodiment, a membrane system may include a hollow tubefilled with a plurality of very thin membrane fibers. Each membranefiber may be another hollow tube in which air flows. The walls of themembrane fiber may be porous and may be configured such that oxygen maypermeate through the wall at a faster rate than nitrogen. In thismanner, a nitrogen rich stream may be allowed to flow out the other endof the fiber. Air outside the fiber and in the hollow tube may be oxygenenriched. Such air may be separated for subsequent uses such asproduction of synthesis gas from a formation.

[0622] In one embodiment, the purity of the nitrogen generated may becontrolled by variation of the flow rate and/or pressure of air throughthe membrane. Increasing air pressure may increase permeation of oxygenmolecules through a fiber wall. Decreasing flow rate may increase theresidence time of oxygen in the membrane and, thus, may increasepermeation through the fiber wall. Air pressure and flow rate may beadjusted to allow a system operator to vary the amount and purity of thenitrogen generated in a relatively short amount of time.

[0623] The amount of N₂ in the enriched air may be adjusted to provide aN:H ratio of about 3:1 for ammonia production. It may be desirable togenerate synthesis gas at a temperature that may favor the production ofcarbon dioxide over carbon monoxide. It may be advantageous for thetemperature of the formation to be between about 400° C. and about 550°C. In another embodiment, it may be desirable for the temperature of theformation to be between about 400° C. and about 450° C. Synthesis gasproduced at such low temperatures may be substantially composed of N₂,H₂, and carbon dioxide with little carbon monoxide.

[0624] As illustrated in FIG. 41, a feed stream for ammonia productionmay be prepared by first feeding synthesis gas stream 1176 into ammoniafeed stream gas processing unit 1178. In ammonia feed stream gasprocessing unit 1178 the feed stream may undergo a shift reaction (toshift the carbon monoxide to carbon dioxide, and to produce additionalhydrogen). Carbon dioxide can also be removed from the feed stream, andthe feed stream can be methanated (to remove residual carbon monoxide).

[0625] In certain embodiments carbon dioxide may be separated from thefeed stream (or any gas stream) by absorption in an amine unit.Membranes or other carbon dioxide separation techniques/equipment mayalso be used to separate carbon dioxide from a feed stream.

[0626] Ammonia feed stream 1180 may be fed to ammonia productionfacility 1182 to produce ammonia 1184. Carbon dioxide 1186 exiting thegas separation unit 1178 (and/or carbon dioxide from other sources) maybe fed, with ammonia 1184, into urea production facility 1188 to produceurea 1190.

[0627] Ammonia and urea may be produced using a carbon containingformation, and using an O₂ rich stream and a N₂ rich stream. The O₂ richstream and synthesis gas generating fluid may be provided to aformation. The formation may be heated, or partially heated, byoxidation of carbon in the formation with the O₂ rich stream. H₂ in thesynthesis gas, and N₂ from the N₂ rich stream, may be provided to anammonia synthesis process to generate ammonia.

[0628]FIG. 42 illustrates a flowchart of an embodiment for production ofammonia and urea from synthesis gas using cryogenically separated air.Air 2000 may be fed into cryogenic air separation unit 2002. Cryogenicseparation involves a distillation process that may occur attemperatures between about (−168) ° C. and (−172) ° C. In otherembodiments, the distillation process may occur at temperatures betweenabout (−165)° C. and (−175)° C. Air may liquefy in these temperatureranges. The distillation process may be operated at a pressure betweenabout 8 bars absolute and about 10 bars absolute. High pressures may beachieved by compressing air and exchanging heat with cold air exitingthe column. Nitrogen is more volatile than oxygen and may come off as adistillate product.

[0629] N₂ 2004 exiting the separator may be utilized in heat exchanger2006 to condense higher molecular weight hydrocarbons from pyrolysisstream 2008 to remove lower molecular weight hydrocarbons from the gasphase into a liquid oil phase. Upgraded gas stream 2010 containing ahigher composition of lower molecular weight hydrocarbons than stream2008 and liquid stream 2012, which includes condensed hydrocarbons, mayexit heat exchanger 2006.

[0630] Oxygen 2014 from cryogenic separation unit 2002 and steam 2016,or water, may be fed into hot carbon containing formation 2018 toproduce synthesis gas 2020 in a continuous process as described herein.It is desirable to generate synthesis gas at a temperature that favorsthe formation of carbon dioxide over carbon monoxide. It may beadvantageous for the temperature of the formation to be between about400° C. and about 550° C. In another embodiment, it may be desirable forthe temperature of the formation to be between about 400° C. and about450° C. Synthesis gas 2020 may be substantially composed of H₂ andcarbon dioxide. Carbon dioxide may be removed from synthesis gas 2020 toprepare a feed stream for ammonia production using amine gas separationunit 2022. H₂ stream 2024 from the gas separation unit and N₂ stream2026 from the heat exchanger may be fed into ammonia production facility2028 to produce ammonia 2030. Carbon dioxide 2032 exiting the gasseparation unit and ammonia 2030 may be fed into urea productionfacility 2034 to produce urea 2036.

[0631] In one embodiment, an ammonia synthesis process feed stream maybe generated by feeding a gas containing N₂ and carbon dioxide to acarbon containing formation. The gas may be flue gas or it may be gasgenerated by an oxidation reaction of O₂ with carbon in another portionof the formation. The gas containing N₂ and carbon dioxide may beprovided to a carbon containing formation. The carbon dioxide in the gasmay adsorb in the formation and be sequestered therein. An exit streammay be produced from the formation. The exit stream may have asubstantially lower percentage of carbon dioxide than the gas enteringthe formation. The nitrogen in the exit gas may be provided to anammonia synthesis process. H₂ in synthesis gas from another portion ofthe formation may be provided to the ammonia synthesis process.

[0632]FIG. 43 illustrates an embodiment of a method for preparing anitrogen stream for an ammonia and urea process. Air 2060 may beinjected into hot carbon containing formation 2062 to produce carbondioxide by oxidation of carbon in the formation. In an embodiment, aheater may be configured to heat at least a portion of the carboncontaining formation to a temperature sufficient to support oxidation ofthe carbon. The temperature sufficient to support oxidation may be, forexample, about 260° C. for coal. Stream 2064 exiting the hot formationmay be composed substantially of carbon dioxide and nitrogen. Nitrogenmay be separated from carbon dioxide by passing the stream through coldspent carbon containing formation 2066. Carbon may be preferentiallyadsorbed versus nitrogen in the cold spent formation 2066. For example,at 50° C. and 0.35 bars, the adsorption of carbon dioxide on a spentportion of coal may be about 72 m³/metric ton compared to about 15.4m³/metric ton for nitrogen. Nitrogen 2068 exiting the cold spent portion2066 may be supplied to ammonia production facility 2070 with H₂ stream2072 to produce ammonia 2074. The H₂ stream may be obtained by methodsdisclosed herein, for example, the methods described in FIGS. 41 and 42.

[0633] Several patterns of heat sources arranged in rings aroundproduction wells may be utilized to create a radial pyrolysis region incoal formations. Various patterns shown in FIGS. 44-57 are describedherein. FIG. 44 illustrates an embodiment of a pattern of heat sources2705 that may create a radial pyrolysis zone. Production well 2701 maybe surrounded by concentric rings 2702, 2703, and 2704 of heat sources2705. Heat sources 2705 in ring 2702 may heat the formation to createradial pyrolysis zone 2710. Fluids may be produced through productionwell 2701. In one embodiment, an average distance between heat sourcesmay be between about 2 m and about 20 m. Alternatively, the averagedistance may be between about 10 m and about 30 m.

[0634] As in other embodiments, it may be desirable to create pyrolysiszones sequentially. Heat sources 2705 nearest production well 2701 maybe activated first, for example, heat sources 2705 in ring 2702. Asubstantially uniform temperature pyrolysis zone may be establishedafter a period of time. Fluids that flow through the pyrolysis zone mayundergo pyrolysis and vaporization. Fluid may flow inward towardsproduction well 2701 due to a pressure differential between a zonearound the production well and the pyrolysis zone, as indicated by thearrows.

[0635] A larger low viscosity zone may be developed by repeatedlyactivating heat sources farther away from the fracture, for example,heat sources 2705 in ring 2704.

[0636] Several patterns of heat sources and production wells may beutilized in embodiments of radial heating zones. The heat sources may bearranged in rings around the production wells. The pattern around eachproduction well may be a hexagon that may contain a number of heatsources.

[0637] In FIG. 45, production well 2701 and heat source 2712 may belocated at the apices of a triangular grid. The triangular grid may bean equilateral triangular grid with sides of length s. Production wells2701 may be spaced at a distance of about 1.732(s). Production well 2701may be disposed at a center of a hexagonal pattern with one ring 2713 ofsix heat sources 2712. Each heat source 2712 may provide substantiallyequal amounts of heat to three production wells. Therefore, each ring2713 of six heat sources 2712 may contribute approximately twoequivalent heat sources per production well 2701.

[0638]FIG. 46 illustrates a pattern of production wells 2701 with aninner hexagonal ring 2713 and an outer hexagonal ring 2715 of heatsources 2712. In this pattern, production wells 2701 may be spaced at adistance of about 2(1.732)s. Heat sources 2712 may be located at allother grid positions. This pattern may result in a ratio of equivalentheat sources to production wells that may approach eleven.

[0639]FIG. 47 illustrates three rings of heat sources 2712 surroundingproduction well 2701. Production well 2701 may be surrounded by ring2713 of six heat sources 2712. Second hexagonally shaped ring 2716 oftwelve heat sources 2712 may surround ring 2713. Third ring 2718 of heatsources 2712 may include twelve heat sources that may providesubstantially equal amounts of heat to two production wells and six heatsources that may provide substantially equal amounts of heat to threeproduction wells. Therefore, a total of eight equivalent heat sourcesmay be disposed on third ring 2718. Production well 2701 may be providedheat from an equivalent of about twenty-six heat sources. FIG. 48illustrates an even larger pattern that may have a greater spacingbetween production wells 2701.

[0640] Alternatively, square patterns may be provided with productionwells placed, for example, in the center of each third square, resultingin four heat sources for each production well. Production wells may beplaced within each fifth square in a square pattern, which may result insixteen heat sources for each production well.

[0641]FIGS. 49, 50, 51, and 52 illustrate alternate embodiments in whichboth production wells and heat sources may be located at the apices of atriangular grid. In FIG. 49, a triangular grid, with a spacing of s, mayhave production wells 2701 spaced at a distance of 2s. A hexagonalpattern may include one ring 2730 of six heat sources 2732. Each heatsource 2732 may provide substantially equal amounts of heat to twoproduction wells 2701. Therefore, each ring 2730 of six heat sources2732 contributes approximately three equivalent heat sources perproduction well 2701.

[0642]FIG. 50 illustrates a pattern of production wells 2701 with innerhexagonal ring 2734 and outer hexagonal ring 2736. Production wells 2701may be spaced at a distance of 3s. Heat sources 2732 may be located atapices of hexagonal ring 2734 and hexagonal ring 2736. Hexagonal ring2734 and hexagonal ring 2736 may include six heat sources each. Thepattern in FIG. 50 may result in a ratio of heat sources 2732 toproduction well 2701 of eight.

[0643]FIG. 51 illustrates a pattern of production wells 2701 also withtwo hexagonal rings of heat sources surrounding each production well.Production well 2701 may be surrounded by ring 2738 of six heat sources2732. Production wells 2701 may be spaced at a distance of 4s. Secondhexagonally shaped ring 2740 may surround ring 2738. Second hexagonallyshaped ring 2740 may include twelve heat sources 2732. This pattern mayresult in a ratio of heat sources 2732 to production wells 2701 that mayapproach fifteen.

[0644]FIG. 52 illustrates a pattern of heat sources 2732 with threerings of heat sources 2732 surrounding each production well 2701.Production wells 2701 may be surrounded by ring 2742 of six heat sources2732. Second ring 2744 of twelve heat sources 2732 may surround ring2742. Third ring 2746 of heat sources 2732 may surround second ring2744. Third ring 2746 may include 6 equivalent heat sources. Thispattern may result in a ratio of heat sources 2732 to production wells2701 that is about 24:1.

[0645]FIGS. 53, 54, 55, and 56 illustrate patterns in which theproduction well may be disposed at a center of a triangular grid suchthat the production well may be equidistant from the apices of thetriangular grid. In FIG. 53, the triangular grid of heater wells with aspacing of s may include production wells 2760 spaced at a distance ofs. Each production well 2760 may be surrounded by ring 2764 of threeheat sources 2762. Each heat source 2762 may provide substantially equalamounts of heat to three production wells 2760. Therefore, each ring2764 of three heat sources 2762 may contribute one equivalent heatsource per production well 2760.

[0646]FIG. 54 illustrates a pattern of production wells 2760 with innertriangular ring 2766 and outer ring 2768. In this pattern, productionwells 2760 may be spaced at a distance of 2s. Heat sources 2762 may belocated at apices of inner ring 2766 and outer ring 2768. Inner ring maycontribute three equivalent heat sources per production well 2760. Outerhexagonal ring 2768 containing three heater wells may contribute oneequivalent heat source per production well 2760. Thus, a total of fourequivalent heat sources may provide heat to production well 2760.

[0647]FIG. 55 illustrates a pattern of production wells with one innertriangular ring of heat sources surrounding each production well, oneinverted triangular ring, and one irregular hexagonal outer ring.Production wells 2760 may be surrounded by ring 2770 of three heatsources 2762. Production wells 2760 may be spaced at a distance of 3s.Irregular hexagonally shaped ring 2772 of nine heat sources 2762 maysurround ring 2770. This pattern may result in a ratio of heat sources2762 to production wells 2760 of three.

[0648]FIG. 56 illustrates triangular patterns of heat sources with threerings of heat sources surrounding each production well. Production wells2760 may be surrounded by ring 2774 of three heat sources 2762.Irregular hexagon pattern 2776 of nine heat sources 2762 may surroundring 2774. Third set 2778 of heat sources 2762 may surround hexagonalpattern 2776. Third set 2778 may contribute four equivalent heat sourcesto production well 2760. A ratio of equivalent heat sources toproduction well 2760 may be sixteen.

[0649] One embodiment for treating at least a portion of a coalformation may include heating the formation from three or more heatsources. At least three of the heat sources may be arranged in asubstantially triangular pattern. At least some hydrocarbons in aselected section of the formation may be pyrolyzed by the heat from thethree or more heat sources. Pyrolyzation fluids generated by pyrolysisof hydrocarbons in the formation may be produced from the formation. Inone embodiment, fluids may be produced through at least one productionwell disposed in the formation.

[0650]FIG. 57 depicts an embodiment of a pattern of heat sources 2705arranged in a triangular pattern. Production well 2701 may be surroundedby triangles 2780, 2782, and 2784 of heat sources 2705. Heat sources2705 in triangles 2780, 2782, and 2784 may provide heat to theformation. The provided heat may raise an average temperature of theformation to a pyrolysis temperature. Pyrolyzation fluids may flow toproduction well 2701. Formation fluids may be produced in productionwell 2701.

[0651]FIG. 58 illustrates a schematic diagram of an embodiment ofsurface facilities 2800 that may be configured to treat a formationfluid. The formation fluid may be produced though a production well asdescribed herein. The formation fluid may include any of a formationfluid produced by any of the methods as described herein. As shown inFIG. 58, surface facilities 2800 may be coupled to well head 2802. Wellhead 2802 may also be coupled to a production well formed in aformation. For example, the well head may be coupled to a productionwell by various mechanical devices proximate an upper surface of theformation. Therefore, a formation fluid produced through a productionwell may also flow through well head 2802. Well head 2802 may beconfigured to separate the formation fluid into gas stream 2804, liquidhydrocarbon condensate stream 2806, and water stream 2808.

[0652] Surface facilities 2800 may be configured such that water stream2808 may flow from well head 2802 to a portion of a formation, to acontainment system, or to a processing unit. For example, water stream2808 may flow from well head 2802 to an ammonia production unit. Thesurface facilities may be configured such that ammonia produced in theammonia production unit may flow to an ammonium sulfate unit. Theammonium sulfate unit may be configured to combine the ammonia withH₂SO₄ or SO₂/SO₃ to produce ammonium sulfate. In addition, the surfacefacilities may be configured such that ammonia produced in the ammoniaproduction unit may flow to a urea production unit. The urea productionunit may be configured to combine carbon dioxide with the ammonia toproduce urea.

[0653] Surface facilities 2800 may be configured such that gas stream2804 may flow through a conduit from well head 2802 to gas treatmentunit 2810. The conduit may include a pipe or any other fluidcommunication mechanism known in the art. The gas treatment unit may beconfigured to separate various components of gas stream 2804. Forexample, the gas treatment unit may be configured to separate gas stream2804 into carbon dioxide stream 2812, hydrogen sulfide stream 2814,hydrogen stream 2816, and stream 2818 that may include, but may not belimited to, methane, ethane, propane, butanes (including n-butane oriso-butane), pentane, ethene, propene, butene, pentene, water orcombinations thereof.

[0654] Surface facilities 2800 may be configured such that the carbondioxide stream may flow through a conduit to a formation, to acontainment system, to a disposal unit, and/or to another processingunit. In addition, the facilities may be configured such that thehydrogen sulfide stream may also flow through a conduit to a containmentsystem and/or to another processing unit. For example, the hydrogensulfide stream may be converted into elemental sulfur in a Claus processunit. The gas treatment unit may also be configured to separate gasstream 2804 into stream 2819 that may include heavier hydrocarboncomponents from gas stream 2804. Heavier hydrocarbon components mayinclude, for example, hydrocarbons having a carbon number of greaterthan about 5. Surface facilities 2800 may be configured such thatheavier hydrocarbon components in stream 2819 may be provided to liquidhydrocarbon condensate stream 2806.

[0655] Surface facilities 2800 may also include processing unit 2821.Processing unit 2821 may be configured to separate stream 2818 into anumber of streams. Each of the number of streams may be rich in apredetermined component or a predetermined number of compounds. Forexample, processing unit 2821 may separate stream 2818 into firstportion 2820 of stream 2818, second portion 2823 of stream 2818, thirdportion 2825 of stream 2818, and fourth portion 2831 of stream 2818.First portion 2820 of stream 2818 may include lighter hydrocarboncomponents such as methane and ethane. The surface facilities may beconfigured such that first portion 2820 of stream 2818 may flow from gastreatment unit 2810 to power generation unit 2822.

[0656] Power generation unit 2822 may be configured for extractinguseable energy from the first portion of stream 2818. For example,stream 2818 may be produced under pressure. In this manner, powergeneration unit may include a turbine configured to generate electricityfrom the first portion of stream 2818. The power generation unit mayalso include, for example, a molten carbonate fuel cell, a solid oxidefuel cell, or other type of fuel cell. The facilities may be furtherconfigured such that the extracted useable energy may be provided touser 2824. User 2824 may include, for example, surface facilities 2800,a heat source disposed within a formation, and/or a consumer of useableenergy.

[0657] Second portion 2823 of stream 2818 may also include lighthydrocarbon components. For example, second portion 2823 of stream 2818may include, but may not be limited to, methane and ethane. Surfacefacilities 2800 may also be configured such that second portion 2823 ofstream 2818 may be provided to natural gas grid 2827. Alternatively,surface facilities may also be configured such that second portion 2823of stream 2818 may be provided to a local market. The local market mayinclude a consumer market or a commercial market. In this manner, thesecond portion 2823 of stream 2818 may be used as an end product or anintermediate product depending on, for example, a composition of thelight hydrocarbon components.

[0658] Third portion 2825 of stream 2818 may include liquefied petroleumgas (“LPG”). Major constituents of LPG may include hydrocarbonscontaining three or four carbon atoms such as propane and butane. Butanemay include n-butane or iso-butane. LPG may also include relativelysmall concentrations of other hydrocarbons such as ethene, propene,butene, and pentene. Depending on the source of LPG and how it has beenproduced, however, LPG may also include additional components. LPG maybe a gas at atmospheric pressure and normal ambient temperatures. LPGmay be liquefied, however, when moderate pressure is applied or when thetemperature is sufficiently reduced. When such moderate pressure isreleased, LPG gas may have about 250 times a volume of LPG liquid.Therefore, large amounts of energy may be stored and transportedcompactly as LPG.

[0659] Surface facilities 2800 may also be configured such that thirdportion 2825 of stream 2818 may be provided to local market 2829. Thelocal market may include a consumer market or a commercial market. Inthis manner, the third portion 2825 of stream 2818 may be used as an endproduct or an intermediate product depending on, for example, acomposition of the LPG. For example, LPG may be used in applications,such as food processing, aerosol propellants, and automotive fuel. LPGmay usually be available in one or two forms for standard heating andcooking purposes: commercial propane and commercial butane. Propane maybe more versatile for general use than butane because, for example,propane has a lower boiling point than butane.

[0660] Surface facilities 2800 may also be configured such that fourthportion 2831 of stream 2818 may flow from the gas treatment unit tohydrogen manufacturing unit 2828. Hydrogen containing stream 2830 isshown exiting hydrogen manufacturing unit 2828. Examples of hydrogenmanufacturing unit 2828 may include a steam reformer and a catalyticflameless distributed combustor with a hydrogen separation membrane.FIG. 59 illustrates an embodiment of a catalytic flameless distributedcombustor. An example of a catalytic flameless distributed combustorwith a hydrogen separation membrane is illustrated in U.S. patentapplication Ser. No. 60/273,354, filed on Mar. 5, 2001, which isincorporated by reference as if fully set forth herein. A catalyticflameless distributed combustor may include fuel line 2850, oxidant line2852, catalyst 2854, and membrane 2856. Fourth portion 2831 of stream2818 may be provided to hydrogen manufacturing unit 2828 as fuel 2858.Fuel 2858 within fuel line 2850 may mix within reaction zone in annularspace 2859 between the fuel line and the oxidant line. Reaction of thefuel with the oxidant in the presence of catalyst 2854 may producereaction products that include H₂. Membrane 2856 may allow a portion ofthe generated H₂ to pass into annular space 2860 between outer wall 2862of oxidant line 2852 and membrane 2856. Excess fuel passing out of fuelline 2850 may be circulated back to entrance of hydrogen manufacturingunit 2828. Combustion products leaving oxidant line 2852 may includecarbon dioxide and other reactions products as well as some fuel andoxidant. The fuel and oxidant may be separated and recirculated back tothe hydrogen manufacturing unit. Carbon dioxide may be separated fromthe exit stream. The carbon dioxide may be sequestered within a portionof a formation or used for an alternate purpose.

[0661] Fuel line 2850 may be concentrically positioned within oxidantline 2852. Critical flow orifices within fuel line 2850 may beconfigured to allow fuel to enter into a reaction zone in annular space2859 between the fuel line and oxidant line 2852. The fuel line maycarry a mixture of water and vaporized hydrocarbons such as, but notlimited to, methane, ethane, propane, butane, methanol, ethanol, orcombinations thereof. The oxidant line may carry an oxidant such as, butnot limited to, air, oxygen enriched air, oxygen, hydrogen peroxide, orcombinations thereof.

[0662] Catalyst 2854 may be located in the reaction zone to allowreactions that produce H₂ to proceed at relatively low temperatures.Without a catalyst and without membrane separation of H₂, a steamreformation reaction may need to be conducted in a series of reactorswith temperatures for a shift reaction occurring in excess of 980° C.With a catalyst and with separation of H₂ from the reaction stream, thereaction may occur at temperatures within a range from about 300° C. toabout 600° C., or within a range from about 400° C. to about 500° C.Catalyst 2854 may be any steam reforming catalyst. In selectedembodiments, catalyst 2854 is a group VIII transition metal, such asnickel. The catalyst may be supported on porous substrate 2864. Thesubstrate may include group III or group IV elements, such as, but notlimited to, aluminum, silicon, titanium, or zirconium. In an embodiment,the substrate is alumina (Al₂O₃).

[0663] Membrane 2856 may remove H₂ from a reaction stream within areaction zone of a hydrogen manufacturing unit 2828. When H₂ is removedfrom the reaction stream, reactions within the reaction zone maygenerate additional H₂. A vacuum may draw H₂ from an annular regionbetween membrane 2856 and wall 2862 of oxidant line 2852. Alternately,H₂ may be removed from the annular region in a carrier gas. Membrane2856 may separate H₂ from other components within the reaction stream.The other components may include, but are not limited to, reactionproducts, fuel, water, and hydrogen sulfide. The membrane may be ahydrogen-permeable and hydrogen selective material such as, but notlimited to, a ceramic, carbon, metal, or combination thereof. Themembrane may include, but is not limited to, metals of group VIII, V,III, or I such as palladium, platinum, nickel, silver, tantalum,vanadium, yttrium, and/or niobium. The membrane may be supported on aporous substrate such as alumina. The support may separate the membrane2856 from catalyst 2854. The separation distance and insulationproperties of the support may help to maintain the membrane within adesired temperature range. In this manner, hydrogen manufacturing unit2828 may be configured to produce hydrogen-rich stream 2830 from thesecond portion stream 2818. The surface facilities may also beconfigured such that hydrogen-rich stream 2830 may flow into hydrogenstream 2816 to form stream 2832. In this manner, stream 2832 may includea larger volume of hydrogen than either hydrogen-rich stream 2830 orhydrogen stream 2816.

[0664] Surface facilities 2800 may be configured such that hydrocarboncondensate stream 2806 may flow through a conduit from well head 2802 tohydrotreating unit 2834. Hydrotreating unit 2834 may be configured tohydrogenate hydrocarbon condensate stream 2806 to form hydrogenatedhydrocarbon condensate stream 2836. The hydrotreater may be configuredto upgrade and swell the hydrocarbon condensate. For example, surfacefacilities 2800 may also be configured to provide stream 2832 (whichincludes a relatively high concentration of hydrogen) to hydrotreatingunit 2834. In this manner, H₂ in stream 2832 may hydrogenate a doublebond of the hydrocarbon condensate, thereby reducing a potential forpolymerization of the hydrocarbon condensate. In addition, hydrogen mayalso neutralize radicals in the hydrocarbon condensate. In this manner,the hydrogenated hydrocarbon condensate may include relatively shortchain hydrocarbon fluids. Furthermore, hydrotreating unit 2834 may beconfigured to reduce sulfur, nitrogen, and aromatic hydrocarbons inhydrocarbon condensate stream 2806. Hydrotreating unit 2834 may be adeep hydrotreating unit or a mild hydrotreating unit. An appropriatehydrotreating unit may vary depending on, for example, a composition ofstream 2832, a composition of the hydrocarbon condensate stream, and/ora selected composition of the hydrogenated hydrocarbon condensatestream.

[0665] Surface facilities 2800 may be configured such that hydrogenatedhydrocarbon condensate stream 2836 may flow from hydrotreating unit 2834to transportation unit 2838. Transportation unit 2838 may be configuredto collect a volume of the hydrogenated hydrocarbon condensate and/or totransport the hydrogenated hydrocarbon condensate to market center 2840.For example, market center 2840 may include, but may not be limited to,a consumer marketplace or a commercial marketplace. A commercialmarketplace may include, but may not be limited to, a refinery. In thismanner, the hydrogenated hydrocarbon condensate may be used as an endproduct or an intermediate product depending on, for example, acomposition of the hydrogenated hydrocarbon condensate.

[0666] Alternatively, surface facilities 2800 may be configured suchthat hydrogenated hydrocarbon condensate stream 2836 may flow to asplitter or an ethene production unit. The splitter may be configured toseparate the hydrogenated hydrocarbon condensate stream into ahydrocarbon stream including components having carbon numbers of 5 or 6,a naphtha stream, a kerosene stream, and a diesel stream. Streamsexiting the splitter may be fed to the ethene production unit. Inaddition, the hydrocarbon condensate stream and the hydrogenatedhydrocarbon condensate stream may be fed to the ethene production unit.Ethene produced by the ethene production unit may be fed to apetrochemical complex to produce base and industrial chemicals andpolymers. Alternatively, the streams exiting the splitter may be fed toa hydrogen conversion unit. A recycle stream may be configured to flowfrom the hydrogen conversion unit to the splitter. The hydrocarbonstream exiting the splitter and the naphtha stream may be fed to a mogasproduction unit. The kerosene stream and the diesel stream may bedistributed as product.

[0667]FIG. 60 illustrates an embodiment of an additional processing unitthat may be included in surface facilities such as the facilitiesdepicted in FIG. 58. Air separation unit 2900 may be configured togenerate nitrogen stream 2902 and oxygen stream 2905. Oxygen stream 2905and steam 2904 may be injected into exhausted coal resource 2906 togenerate synthesis gas 2907. Produced synthesis gas 2907 may be providedto Shell Middle Distillates process unit 2910 that may be configured toproduce middle distillates 2912. In addition, produced synthesis gas2907 may be provided to catalytic methanation process unit 2914 that maybe configured to produce natural gas 2916. Produced synthesis gas 2907may also be provided to methanol production unit 2918 to producemethanol 2920. Furthermore, produced synthesis gas 2907 may be providedto process unit 2922 for production of ammonia and/or urea 2924, andfuel cell 2926 that may be configured to produce electricity 2928.Synthesis gas 2907 may also be routed to power generation unit 2930,such as a turbine or combustor, to produce electricity 2932.

[0668]FIG. 61 illustrates an example of a square pattern of heat sources3000 and production wells 3002. Heat sources 3000 are disposed atvertices of squares 3010. Production well 3002 is placed in a center ofevery third square in both x- and y-directions. Midlines 3006 are formedequidistant to two production wells 3002, and perpendicular to a lineconnecting such production wells. Intersections of midlines 3006 atvertices 3008 form unit cell 3012. Heat source 3000 b and heat source3000 c are only partially within unit cell 3012. Only the one-halffraction of heat source 3000 b and the one-quarter fraction of heatsource 3000 c within unit cell 3012 are configured to provide heatwithin unit cell 3012. The fraction of heat source 3000 outside of unitcell 3012 is configured to provide heat outside of unit cell 3012. Thenumber of heat sources 3000 within one unit cell 3012 is a ratio of heatsources 3000 per production well 3002 within the formation.

[0669] The total number of heat sources inside unit cell 3012 isdetermined by the following method:

[0670] (a) 4 heat sources 3000 a inside unit cell 3012 are counted asone heat source each;

[0671] (b) 8 heat sources 3000 b on midlines 3006 are counted asone-half heat source each; and

[0672] (c) 4 heat sources 3000 c at vertices 3008 are counted asone-quarter heat source each.

[0673] The total number of heat sources is determined from adding theheat sources counted by, (a) 4, (b) 8/2=4, and (c) 4/4=1, for a totalnumber of 9 heat sources 3000 in unit cell 3012. Therefore, a ratio ofheat sources 3000 to production wells 3002 is determined as 9:1 for thepattern illustrated in FIG. 61.

[0674]FIG. 62 illustrates an example of another pattern of heat sources3000 and production wells 3002. Midlines 3006 are formed equidistantfrom the two production wells 3002, and perpendicular to a lineconnecting such production wells. Unit cell 3014 is determined byintersection of midlines 3006 at vertices 3008. Twelve heat sources 3000are counted in unit cell 3014 by a method as described in the aboveembodiments, of which are six are whole sources of heat, and six are onethird sources of heat (with the other two thirds of heat from such sixwells going to other patterns). Thus, a ratio of heat sources 3000 toproduction wells 3002 is determined as 8:1 for the pattern illustratedin FIG. 62. An example of a pattern of heat sources is illustrated inU.S. Pat. No. 2,923,535 issued to Ljungstrom, which is incorporated byreference as if fully set forth herein.

[0675] In certain embodiments, a triangular pattern of heat sources mayprovide advantages when compared to alternative patterns of heatsources, such as squares, hexagons, and hexagons with additional heatersinstalled halfway between the hexagon comers (12 to 1 pattern). Squares,hexagons, and the 12:1 patterns are disclosed in U.S. Pat. No. 2,923,535and/or in U.S. Pat. No. 4,886,118. For example, a triangular pattern ofheat sources may provide more uniform heating of a coal formationresulting from a more uniform temperature distribution of an area of aformation heated by the pattern of heat sources.

[0676]FIG. 63 illustrates an embodiment of triangular pattern 3100 ofheat sources 3102. FIG. 64 illustrates an embodiment of square pattern3101 of heat sources 3103. FIG. 65 illustrates an embodiment ofhexagonal pattern 3104 of heat sources 3106. FIG. 66 illustrates anembodiment of 12 to 1 pattern 3105 of heat sources 3107. A temperaturedistribution for all patterns may be determined by an analytical method.The analytical method may be simplified by analyzing only temperaturefields within “confined” patterns (e.g., hexagons), i.e., completelysurrounded by others. In addition, the temperature field may beestimated to be a superposition of analytical solutions corresponding toa single heat source.

[0677] The comparisons of patterns of heat sources were evaluated forthe same heater well density and the same heating input regime. Forexample, a number of heat sources per unit area in a triangular patternis the same as the number of heat sources per unit area in the 10 mhexagonal pattern if the space between heat sources is increased toabout 12.2 m in the triangular pattern. The equivalent spacing for asquare pattern would be 11.3 m, while the equivalent spacing for a 12 to1 pattern would be 15.7 m.

[0678] A triangular pattern of heat sources may have, for example, ashorter total process time than a square, hexagonal or 12 to 1 patternof heat sources for the same heater well density. A total process timemay include a time required for an average temperature of a heatedportion of a formation to reach a target temperature and a time requiredfor a temperature at a coldest spot within the heated portion to reachthe target temperature. For example, heat may be provided to the portionof the formation until an average temperature of the heated portionreaches the target temperature. After the average temperature of theheated portion reaches the target temperature, an energy supply to theheat sources may be reduced such that less or minimal heat may beprovided to the heated portion. An example of a target temperature maybe approximately 340° C. The target temperature, however, may varydepending on, for example, formation composition and/or formationconditions such as pressure.

[0679] A spacing of heat sources in a triangular pattern, which mayyield the same process time as a hexagonal pattern having about a 10.0 mspace between heat sources, may be equal to approximately 14.3 m. Inthis manner, the total process time of a hexagonal pattern may beachieved by using about 26% less heat sources than may be included insuch a hexagonal pattern. In this manner, such a triangular pattern mayhave substantially lower capital and operating costs. As such, thistriangular pattern may also be more economical than a hexagonal pattern.

[0680]FIG. 12 depicts an embodiment of a natural distributed combustor.In one experiment the embodiment schematically shown in FIG. 12 was usedto heat high volatile bituminous C coal in situ. A heating well wasconfigured to be heated with electrical resistance heaters and/or anatural distributed combustor such as is schematically shown in FIG. 12.Thermocouples were located every 2 feet along the length of the naturaldistributed combustor (along conduit 532 as is schematically shown inFIG. 12). The coal was first heated with electrical resistance heatersuntil pyrolysis was complete proximate the well. FIG. 92 depicts squaredata points measured during electrical resistance heating at variousdepths in the coal after the temperature profile had stabilized (thecoal seam was about 16 feet thick starting at about 28 feet of depth).At this point heat energy was being supplied at about 300 Watts perfoot. Air was subsequently injected via conduit 532 at graduallyincreasing rates, and electric power was substantially simultaneouslydecreased. Combustion products were removed from the reaction zone in anannulus surrounding conduit 532 and the electrical resistance heater.The electric power was decreased at rates that would approximatelyoffset heating provided by the combustion of the coal caused by thenatural distributed combustor. Air rates were increased, and power rateswere decreased, over a period of about 2 hours until no electric powerwas being supplied. FIG. 92 depicts diamond data points measured duringnatural distributed combustion heating (without any electricalresistance heating) at various depths in the coal after the temperatureprofile had stabilized. As can be seen in FIG. 92, the naturaldistributed combustion heating provided a temperature profile that iscomparable to the electrical resistance temperature profile. Thisexperiment demonstrated that natural distributed combustors can provideformation heating that is comparable to the formation heating providedby electrical resistance heaters. This experiment was repeated atdifferent temperatures, and in two other wells, all with similarresults.

[0681] Numerical calculations have been made for a natural distributedcombustor system configured to heat a coal formation. A commerciallyavailable program called PRO-II was used to make example calculationsbased on a conduit of diameter 6.03 cm with a wall thickness of 0.39 cm.The conduit was disposed in an opening in the formation with a diameterof 14.4 cm. The conduit had critical flow orifices of 1.27 mm diameterspaced 183 cm apart. The conduit was configured to heat a formation of91.4 meters thick. A flow rate of air was 1.70 standard cubic meters perminute through the critical flow orifices. A pressure of air at theinlet of the conduit was 7 bars absolute. Exhaust gases had a pressureof 3.3 bars absolute. A heating output of 1066 watts per meter was used.A temperature in the opening was set at 760° C. The calculationsdetermined a minimal pressure drop within the conduit of about 0.023bar. The pressure drop within the opening was less than 0.0013 bar.

[0682]FIG. 67 illustrates extension (in meters) of a reaction zonewithin a coal formation over time (in years) according to the parametersset in the calculations. The width of the reaction zone increases withtime as the carbon was oxidized proximate to the center.

[0683] Numerical calculations have been made for heat transfer using aconductor-in-conduit heater. Calculations were made for a conductorhaving a diameter of about 1 inch (2.54 cm) disposed in a conduit havinga diameter of about 3 inches (7.62 cm). The conductor-in-conduit heaterwas disposed in an opening of a carbon containing formation having adiameter of about 6 inches (15.24 cm). An emissivity of the carboncontaining formation was maintained at a value of 0.9, which is expectedfor geological materials. The conductor and the conduit were givenalternate emissivity values of high emissivity (0.86), which is commonfor oxidized metal surfaces, and low emissivity (0.1), which is forpolished and/or un-oxidized metal surfaces. The conduit was filled witheither air or helium. Helium is known to be a more thermally conductivegas than air. The space between the conduit and the opening was filledwith a gas mixture of methane, carbon dioxide, and hydrogen gases. Twodifferent gas mixtures were used. The first gas mixture had molefractions of 0.5 for methane, 0.3 for carbon dioxide, and 0.2 forhydrogen. The second gas mixture had mole fractions of 0.2 for methane,0.2 for carbon dioxide, and 0.6 for hydrogen.

[0684]FIG. 68 illustrates a calculated ratio of conductive heat transferto radiative heat transfer versus a temperature of a face of the coalformation in the opening for an air filled conduit. The temperature ofthe conduit was increased linearly from 93° C. to 871° C. The ratio ofconductive to radiative heat transfer was calculated based on emissivityvalues, thermal conductivities, dimensions of the conductor, conduit,and opening, and the temperature of the conduit. Line 3204 is calculatedfor the low emissivity value (0.1). Line 3206 is calculated for the highemissivity value (0.86). A lower emissivity for the conductor and theconduit provides for a higher ratio of conductive to radiative heattransfer to the formation. The decrease in the ratio with an increase intemperature may be due to a reduction of conductive heat transfer withincreasing temperature. As the temperature on the face of the formationincreases, a temperature difference between the face and the heater isreduced, thus reducing a temperature gradient that drives conductiveheat transfer.

[0685]FIG. 69 illustrates a calculated ratio of conductive heat transferto radiative heat transfer versus a temperature at a face of the coalformation in the opening for a helium filled conduit. The temperature ofthe conduit was increased linearly from 93° C. to 871° C. The ratio ofconductive to radiative heat transfer was calculated based on emissivityvalues; thermal conductivities; dimensions of the conductor, conduit,and opening; and the temperature of the conduit. Line 3208 is calculatedfor the low emissivity value (0.1). Line 3210 is calculated for the highemissivity value (0.86). A lower emissivity for the conductor and theconduit again provides for a higher ratio of conductive to radiativeheat transfer to the formation. The use of helium instead of air in theconduit significantly increases the ratio of conductive heat transfer toradiative heat transfer. This may be due to a thermal conductivity ofhelium being about 5.2 to about 5.3 times greater than a thermalconductivity of air.

[0686]FIG. 70 illustrates temperatures of the conductor, the conduit,and the opening versus a temperature at a face of the coal formation fora helium filled conduit and a high emissivity of 0.86. The opening has agas mixture equivalent to the second mixture described above having ahydrogen mole fraction of 0.6. Opening temperature 3216 was linearlyincreased from 93° C. to 871° C. Opening temperature 3216 was assumed tobe the same as the temperature at the face of the coal formation.Conductor temperature 3212 and conduit temperature 3214 were calculatedfrom opening temperature 3216 using the dimensions of the conductor,conduit, and opening, values of emissivities for the conductor, conduit,and face, and thermal conductivities for gases (helium, methane, carbondioxide, and hydrogen). It may be seen from the plots of temperatures ofthe conductor, conduit, and opening for the conduit filled with helium,that at higher temperatures approaching 871° C., the temperatures of theconductor, conduit, and opening begin to substantially equilibrate.

[0687]FIG. 71 illustrates temperatures of the conductor, the conduit,and the opening versus a temperature at a face of the coal formation foran air filled conduit and a high emissivity of 0.86. The opening has agas mixture equivalent to the second mixture described above having ahydrogen mole fraction of 0.6. Opening temperature 3216 was linearlyincreased from 93° C. to 871° C. Opening temperature 3216 was assumed tobe the same as the temperature at the face of the coal formation.Conductor temperature 3212 and conduit temperature 3214 were calculatedfrom opening temperature 3216 using the dimensions of the conductor,conduit, and opening, values of emissivities for the conductor, conduit,and face, and thermal conductivities for gases (air, methane, carbondioxide, and hydrogen). It may be seen from the plots of temperatures ofthe conductor, conduit, and opening for the conduit filled with air,that at higher temperatures approaching 871° C., the temperatures of theconductor, conduit, and opening begin to substantially equilibrate, asseen for the helium filled conduit with high emissivity.

[0688]FIG. 72 illustrates temperatures of the conductor, the conduit,and the opening versus a temperature at a face of the coal formation fora helium filled conduit and a low emissivity of 0.1. The opening has agas mixture equivalent to the second mixture described above having ahydrogen mole fraction of 0.6. Opening temperature 3216 was linearlyincreased from 93° C. to 871° C. Opening temperature 3216 was assumed tobe the same as the temperature at the face of the coal formation.Conductor temperature 3212 and conduit temperature 3214 were calculatedfrom opening temperature 3216 using the dimensions of the conductor,conduit, and opening, values of emissivities for the conductor, conduit,and face, and thermal conductivities for gases (helium, methane, carbondioxide, and hydrogen). It may be seen from the plots of temperatures ofthe conductor, conduit, and opening for the conduit filled with helium,that at higher temperatures approaching 871° C., the temperatures of theconductor, conduit, and opening do not begin to substantiallyequilibrate as seen for the high emissivity example shown in FIG. 70.Also, higher temperatures in the conductor and the conduit are neededfor an opening and face temperature of 871° C. than as for the exampleshown in FIG. 70. Thus, increasing an emissivity of the conductor andthe conduit may be advantageous in reducing operating temperaturesneeded to produce a desired temperature in a coal formation. Suchreduced operating temperatures may allow for the use of less expensivealloys for metallic conduits .

[0689]FIG. 73 illustrates temperatures of the conductor, the conduit,and the opening versus a temperature at a face of the coal formation foran air filled conduit and a low emissivity of 0.1. The opening has a gasmixture equivalent to the second mixture described above having ahydrogen mole fraction of 0.6. Opening temperature 3216 was linearlyincreased from 93° C. to 871° C. Opening temperature 3216 was assumed tobe the same as the temperature at the face of the coal formation.Conductor temperature 3212 and conduit temperature 3214 were calculatedfrom opening temperature 3216 using the dimensions of the conductor,conduit, and opening, values of emissivities for the conductor, conduit,and face, and thermal conductivities for gases (air, methane, carbondioxide, and hydrogen). It may be seen from the plots of temperatures ofthe conductor, conduit, and opening for the conduit filled with helium,that at higher temperatures approaching 871° C., the temperatures of theconductor, conduit, and opening do not begin to substantiallyequilibrate as seen for the high emissivity example shown in FIG. 71.Also, higher temperatures in the conductor and the conduit are neededfor an opening and face temperature of 871° C. than as for the exampleshown in FIG. 71. Thus, increasing an emissivity of the conductor andthe conduit may be advantageous in reducing operating temperaturesneeded to produce a desired temperature in a coal formation. Suchreduced operating temperatures may provide for a lesser metallurgicalcost associated with materials that require less substantial temperatureresistance (e.g., a lower melting point).

[0690] Calculations were also made using the first mixture of gas havinga hydrogen mole fraction of 0.2. The calculations resulted insubstantially similar results to those for a hydrogen mole fraction of0.6.

[0691] A series of experiments was conducted to determine the effects ofvarious properties of coal formations on properties of fluids producedfrom such coal formations. The fluids may be produced according to anyof the embodiments as described herein. The series of experimentsincluded organic petrography, proximate/ultimate analyses, Rock-Evalpyrolysis, Leco Total Organic Carbon (“TOC”), Fischer Assay, andpyrolysis-gas chromatography. Such a combination of petrographic andchemical techniques may provide a quick and inexpensive method fordetermining physical and chemical properties of coal and for providing acomprehensive understanding of the effect of geochemical parameters onpotential oil and gas production from coal pyrolysis. The series ofexperiments were conducted on forty-five cubes of coals to determinesource rock properties of each coal and to assess potential oil and gasproduction from each coal.

[0692] Organic petrology is the study, mostly under the microscope, ofthe organic constituents of coal and other rocks. The petrography ofcoal is important since it affects the physical and chemical nature ofthe coal. The ultimate analysis refers to a series of defined methodsthat are used to determine the carbon, hydrogen, sulfur, nitrogen, ash,oxygen, and the heating value of a coal. Proximate analysis is themeasurement of the moisture, ash, volatile matter, and fixed carboncontent of a coal.

[0693] Rock-Eval pyrolysis is a petroleum exploration tool developed toassess the generative potential and thermal maturity of prospectivesource rocks. A ground sample may be pyrolyzed in a helium atmosphere.For example, the sample may be initially heated and held at atemperature of 300° C. for 5 minutes. The sample may be further heatedat a rate of 25° C./min to a final temperature of 600° C. The finaltemperature may be maintained for 1 minute. The products of pyrolysismay be oxidized in a separate chamber at 580° C. to determined the totalorganic carbon content. All components generated may be split into twostreams passing through a flame ionization detector, which may measurehydrocarbon and a thermal conductivity detector, which may measure CO₂.

[0694] Leco Total Organic Carbon (“TOC”) involves combustion of coal.For example, a small sample (about 1 gram) is heated to 1500° C. in ahigh-frequency electrical field under an oxygen atmosphere. Conversionof carbon to carbon dioxide is measured volumetrically. Pyrolysis-gaschromatography may be used for quantitative and qualitative analysis ofpyrolysis gas.

[0695] Coals of different ranks and vitrinite reflectances were treatedin a laboratory to simulate an in situ conversion process. The differentcoal samples were heated at a rate of about 2° C./day and at a pressureof 1 bar or 4.4 bars absolute. FIG. 77 shows weight percents ofparaffins plotted against vitrinite reflectance. As shown in FIG. 77weight percent of paraffins in the produced oil increases at vitrinitereflectances of the coal below about 0.9%. In addition, a weight percentof paraffins in the produced oil approaches maximum at a vitrinitereflectance of about 0.9%. FIG. 78 depicts weight percent of in theproduced oil plotted versus vitrinite reflectance. As shown in FIG. 78 aweight percent of cycloalkanes in the oil produced increased asvitrinite reflectance increased. Weight percentages of a sum ofparaffins and cycloalkanes is plotted versus vitrinite reflectance inFIG. 79. In some embodiments, an in situ conversion process may beutilized to produce phenol. Phenol generation may increase when a fluidpressure within the formation is maintained at a lower pressure. Phenolweight percent in the produced oil is depicted in FIG. 80. A weightpercent of phenol in the produced oil decreases as the vitrinitereflectance increases. FIG. 81 illustrates a weight percentage ofaromatics in the hydrocarbon fluids plotted against vitrinitereflectance. As shown in FIG. 81, a weight percent of aromatics in theproduced oil decreases below a vitrinite reflectance of about 0.9%. Aweight percent of aromatics in the produced oil increases above avitrinite reflectance of about 0.9%. FIG. 82 depicts a ratio ofparaffins to aromatics 3680 and a ratio of aliphatics to aromatics 3682plotted versus vitrinite reflectance. Both ratios increase to a maximumat a vitrinite reflectance between about 0.7% and about 0.9%. Above avitrinite reflectance of about 0.9%, both ratios decrease as vitrinitereflectance increases.

[0696]FIG. 96 depicts the condensable hydrocarbon compositions, andcondensable hydrocarbon API gravities, that were produced when variousranks of coal were treated as is described above for FIGS. 77-82. InFIG. 96, “SubC” means a rank of sub-bituminous C coal, “SubB” means arank of sub-bituminous B coal, “SubA” means a rank of sub-bituminous Acoal, “HVC” means a rank of high volatile bituminous C coal, “HVB/A”means a rank of high volatile bituminous coal at the border between Band A rank coal, “MV” means a rank medium volatile bituminous coal, and“Ro” means vitrinite reflectance. As can be seen in FIG. 96, certainranks of coal will produce different compositions when treated incertain embodiments described herein. For instance, in manycircumstances it may be desirable to treat coal having a rank of HVB/Abecause such coal, when treated, has the highest API gravity, thehighest weight percent of paraffins, and the highest weight percent ofthe sum of paraffins and cycloalkanes.

[0697] Results were also displayed as a yield of products. FIG. 83-86illustrate the yields of components in terms of m³ of product per kg ofcoal formation, when measured on a dry, ash free basis. As illustratedin FIG. 83 the yield of paraffins increased as the vitrinite reflectanceof the coal increased. However, for coals with a vitrinite reflectancegreater than about 0.7-0.8% the yield of paraffins fell offdramatically. In addition, a yield of cycloalkanes followed similartrends as the paraffins, increasing as the vitrinite reflectance of coalincreased and decreasing for coals with a vitrinite reflectance greaterthan about 0.7% or 0.8% as illustrated in FIG. 84. FIG. 85 illustratesthe increase of both paraffins and cycloalkanes as the vitrinitereflectance of coal increases to about 0.7% or 0.8%. As illustrated inFIG. 86 the yield of phenols may be relatively low for coal containingmaterial with a vitrinite reflectance of less than about 0.3% andgreater than about 1.25%. Production of phenols may be desired due tothe value of phenol as a feedstock for chemical synthesis.

[0698] As demonstrated in FIG. 87, the API gravity appears to increasesignificantly when the vitrinite reflectance is greater than about0.40%. In FIG. 88 the relationship between coal rank, i.e., vitrinitereflectance, and a yield of condensable hydrocarbons (in gallons per tonon a dry ash free basis) from a coal formation. The yield in thisexperiment appears to be in an optimal range when the coal has avitrinite reflectance greater than about 0.4% to less than about 1.3%.

[0699]FIG. 89 illustrates a plot of CO₂ yield of coal having variousvitrinite reflectances. In FIGS. 89 and 90, CO₂ yield is set forth inweight percent on a dry ash free basis. As shown in FIG. 89, at leastsome CO₂ was released from all of the coal samples. Such CO₂ productionmay correspond to various oxygenated functional groups present in theinitial coal samples. A yield of CO₂ produced from low-rank coal sampleswas significantly higher than a production from high-rank coal samples.Low-rank coals may include lignite and sub-bituminous brown coals.High-rank coals may include semi-anthracite and anthracite coal. FIG. 90illustrates a plot of CO₂ yield from a portion of a coal formationversus the atomic O/C ratio within a portion of a coal formation. As O/Catomic ratio increases, a CO₂ yield increases.

[0700] A slow heating process may produce condensed hydrocarbon fluidshaving API gravities in a range of 22 to 50, and average molecularweights of about 150 g/gmol to about 250 g/gmol. These properties may becompared to properties of condensed hydrocarbon fluids produced by exsitu retorting of coal as reported in Great Britain Published PatentApplication No. GB 2,068,014 A, which is incorporated by reference as iffully set forth herein. For example, properties of condensed hydrocarbonfluids produced by an ex situ retort process include API gravities of1.9 to 7.9 produced at temperature of 521° C. and 427° C., respectively.

[0701] Table 4 shows a comparison of gas compositions, in percentvolume, obtained from in situ gasification of coal using air injectionto heat the coal, in situ gasification of coal using oxygen injection toheat the coal, and in situ gasification of coal in a reducing atmosphereby thermal pyrolysis heating as described in embodiments herein. TABLE 4Gasification Gasification Thermal Pyrolysis With Air With Oxygen HeatingH₂ 18.6% 35.5% 16.7% Methane  3.6%  6.9% 61.9% Nitrogen and Argon 47.5% 0.0  0.0 Carbon Monoxide 16.5% 31.5%  0.9% Carbon Dioxide 13.1% 25.0% 5.3% Ethane  0.6%  1.1% 15.2%

[0702] As shown in Table 4, gas produced according to an embodimentdescribed herein may be treated and sold through existing natural gassystems. In contrast, gas produced by typical in situ gasificationprocesses may not be treated and sold through existing natural gassystems. For example, a heating value of the gas produced bygasification with air was 6000 KJ/m³, and a heating value of gasproduced by gasification with oxygen was 11,439 KJ/m. In contrast, aheating value of the gas produced by thermal conductive heating was39,159 KJ/m³.

[0703] Experiments were conducted to determine the difference betweentreating relatively large solid blocks of coal versus treatingrelatively small loosely packed particles of coal.

[0704] As illustrated in FIG. 91, coal 3700 in the shape of a cube washeated to pyrolyze the coal. Heat was provided to cube 3700 from heatsource 3704 inserted into the center of the cube and also from heatsources 3702 located on the sides of the cube. The cube was surroundedby insulation 3705. The temperature was raised simultaneously using heatsources 3704, 3702 at a rate of about 2° C./day at atmospheric pressure.Measurements from temperature gauges 3706 were used to determine anaverage temperature of cube 3700. Pressure in cube 3700 was monitoredwith pressure gauge 3708. The fluids produced from the cube of coal werecollected and routed through conduit 3709. Temperature of the productfluids was monitored with temperature gauge 3706 on conduit 3709. Apressure of the product fluids was monitored with pressure gauge 3708 onconduit 3709. A hydrocarbon condensate was separated from anon-condensable fluid in separator 3710. Pressure in separator 3710 wasmonitored with pressure gauge 3708. A portion of the non-condensablefluid was routed through conduit 3711 to gas analyzers 3712 forcharacterization. Grab samples were taken from a grab sample port 3714.Temperature of the non-condensable fluids was monitored with temperaturegauge 3706 on conduit 3711. A pressure of the non-condensable fluids wasmonitored with pressure gauge 3708 on conduit 3711. The remaining gaswas routed through a flow meter 3716, a carbon bed 3718, and vented tothe atmosphere. The produced hydrocarbon condensate was collected andanalyzed to determine the composition of the hydrocarbon condensate.

[0705]FIG. 75 illustrates a drum experimental apparatus. This apparatuswas used to test coal. Electrical heater 3404 and bead heater 3402 wereused to uniformly heat contents of drum 3400. Insulation 3405 surroundsdrum 3400. Contents of drum 3400 were heated at a rate of about 2°C./day at various pressures. Measurements from temperature gauges 3406were used to determine an average temperature in drum 3400. Pressure inthe drum was monitored with pressure gauge 3408. Product fluids wereremoved from drum 3400 through conduit 3409. Temperature of the productfluids was monitored with temperature gauge 3406 on conduit 3409. Apressure of the product fluids was monitored with pressure gauge 3408 onconduit 3409. Product fluids were separated in separator 3410. Separator3410 separated product fluids into condensable and non-condensableproducts. Pressure in separator 3410 was monitored with pressure gauge3408. Non-condensable product fluids were removed through conduit 3411.A composition of a portion of non-condensable product fluids removedfrom separator 3410 was determined by gas analyzer 3412. A portion ofcondensable product fluids were removed from separator 3410.Compositions of the portion of condensable product fluids collected weredetermined by external analysis methods. Temperature of thenon-condensable fluids was monitored with temperature gauge 3406 onconduit 3411. A pressure of the non-condensable fluids was monitoredwith pressure gauge 3408 on conduit 3411. Flow of non-condensable fluidsfrom separator 3410 was determined by flow meter 3416. Fluids measuredin flow meter 3416 were collected and neutralized in carbon bed 3418.Gas samples were collected in gas container 3414.

[0706] A large block of high volatile bituminous B Fruitland coal wasseparated into two portions. One portion (about 550 kg) was ground intosmall pieces and tested in a coal drum. The coal was ground to anapproximate diameter of about 6.34×10⁻⁴ m. The results of such testingare depicted with the circles in FIGS. 93 and 95. One portion (a cubehaving sides measuring 0.3048 m) was tested in a coal cube experiment.The results of such testing are depicted with the squares in FIGS. 93and 95.

[0707]FIG. 93 is a plot of gas phase compositions from experiments on acoal cube and a coal drum for H₂ 3724, methane 3726, ethane 3780,propane 3781, n-butane 3782, and other hydrocarbons 3783 as a functionof temperature. As can be seen for FIG. 93, the non-condensable fluidsproduced from pyrolysis of the cube and the drum had similarconcentrations of the various hydrocarbons generated within the coal. InFIG. 93 these results were so similar that only one line was drawn forethane 3780, propane 3781, n-butane 3782, and other hydrocarbons 3783for both the cube and the drum results, and the two lines that weredrawn for H₂ (3724 a and 3724 b) and the two lines drawn for methane(3726 a and 3726 b) were in both instances very close to each other.Crushing the coal did not have an apparent effect on the pyrolysis ofthe coal. The peak in methane production 3726 occurred at about 450° C.At higher temperatures methane cracks to hydrogen, so the methaneconcentration decreases while the hydrogen content 3724 increases.

[0708]FIG. 94 illustrates a plot of cumulative production of gas as afunction of temperature from heating coal in the cube and coal in thedrum. Line 3790 represents gas production from coal in the drum and line3791 represents gas production from coal in the cube. As demonstrated byFIG. 94, the production of gas in both experiments yielded similarresults, even though the particle sizes were dramatically differentbetween the two experiments.

[0709]FIG. 95 illustrates cumulative condensable hydrocarbons producedin the cube and drum experiments. Line 3720 represents cumulativecondensable hydrocarbons production from the cube experiment, and line3722 represents cumulative condensable hydrocarbons production from thedrum experiment. As demonstrated by FIG. 95, the production ofcondensable hydrocarbons in both experiments yielded similar results,even though the particle sizes were dramatically different between thetwo experiments. Production of condensable hydrocarbons is substantiallycomplete when the temperature reached about 390° C. In both experimentsthe condensable hydrocarbons had an API gravity of about 37 degrees.

[0710] As shown in FIG. 93, methane started to be produced attemperatures at or above about 270° C. Since the experiments wereconduced at atmospheric pressure, it is believed that the methane isproduced from the pyrolysis, and not from mere desorption. Between about270° C. and about 400° C., condensable hydrocarbons, methane and H₂ wereproduced as shown in FIGS. 93, 94, and 95. FIG. 93 shows that above atemperature of about 400° C. methane and H₂ continue to be produced.Above about 450° C., however, methane concentration decreased in theproduced gases whereas the produced gases contained increased amounts ofH₂. If heating were continued, eventually all H₂ remaining in the coalwould be depleted, and production of gas from the coal would cease.FIGS. 93-95 indicate that the ratio of a yield of gas to a yield ofcondensable hydrocarbons will increase as the temperature increasesabove about 390° C.

[0711] FIGS. 93-95 demonstrate that particle size did not substantiallyaffect the quality of condensable hydrocarbons produced from the treatedcoal, the quantity of condensable hydrocarbons produced from the treatedcoal, the amount of gas produced from the treated coal, the compositionof the gas produced from the treated coal, the time required to producethe condensable hydrocarbons and gas from the treated coal, or thetemperatures required to produce the condensable hydrocarbons and gasfrom the treated coal. In essence a block of coal yielded substantiallythe same results from treatment as small particles of coal. As such, itis believed that scale-up issues when treating coal will notsubstantially affect treatment results.

[0712] An experiment was conducted to determine an effect of heating onthermal conductivity and thermal diffusivity of a portion of a coalformation. Thermal pulse tests performed in situ in a high volatilebituminous C coal at the field pilot site showed a thermal conductivitybetween 2.0×10⁻³−2.39×10⁻³ cal/cm sec ° C. (0.85 to 1.0 W/(m° K)) at 20°C. Ranges in these values were due to different measurements betweendifferent wells. The thermal diffusivity was 4.8×10⁻³ cm²/s at 20° C.(the range was from about 4.1×10⁻³ to about 5.7×10⁻³ cm²/s at 20° C.).It is believed that these measured values for thermal conductivity andthermal diffusivity are substantially higher than would be expectedbased on literature sources (e.g., about three times higher in manyinstances).

[0713] An initial value for thermal conductivity from the in situexperiment is plotted versus temperature in FIG. 97 (this initial valueis point 3743 in FIG. 97). Additional points for thermal conductivity(i.e., all of the other values for line 3742 shown in FIG. 97) wereassessed by calculating thermal conductivities using temperaturemeasurements in all of the wells shown in FIG. 99, total heat input fromall heaters shown in FIG. 99, measured heat capacity and density for thecoal being treated, gas and liquids production data (e.g., composition,quantity, etc.), etc. For comparison, these assessed thermalconductivity values (see line 3742) were plotted with data reported intwo papers from S. Badzioch, et al. (1964) and R. E. Glass (1984) (seeline 3740). As illustrated in FIG. 97, the assessed thermalconductivities from the in situ experiment were higher than reportedvalues for thermal conductivities. The difference may be at leastpartially accounted for if it is assumed that the reported values do nottake into consideration the confined nature of the coal in an in situapplication. Because the reported values for thermal conductivity ofcoal are relatively low, they discourage the use of in situ heating forcoal.

[0714]FIG. 97 illustrates a decrease in the assessed thermalconductivity values 3742 at about 100° C. It is believed that thisdecrease in thermal conductivity was caused by water vaporizing in thecracks and void spaces (water vapor has a lower thermal conductivitythan liquid water). At about 350° C., the thermal conductivity began toincrease, and it increased substantially as the temperature increased to700° C. It is believed that the increases in thermal conductivity werethe result of molecular changes in the carbon structure. As the carbonwas heated it became more graphitic which is illustrated in Table 5 byan increased vitrinite reflectance after pyrolysis. As void spacesincreased due to fluid production, heat was increasingly transferred byradiation and/or convection. In addition, concentrations of hydrogen inthe void spaces were raised due to pyrolysis and generation of synthesisgas.

[0715] Three data points 3744 of thermal conductivities under highstress were derived from laboratory tests on the same high volatilebituminous C coal used for the in situ field pilot site (see FIG. 97) Inthe laboratory tests a sample of such coal was stressed from alldirections, and heated relatively quickly. These thermal conductivitieswere determined at higher stress (i.e., 27.6 bars absolute), as comparedto the stress in the in situ field pilot (which were about 3 barsabsolute). Thermal conductivity values 3744 demonstrate that theapplication of stress increased the thermal conductivity of the coal attemperatures of 150° C., 250° C., and 350° C. It is believed that higherthermal conductivity values were obtained from stressed coal because thestress closed at least some cracks/void spaces and/or prevented newcracks/void spaces from forming.

[0716] Using the reported values for thermal conductivity and thermaldiffusivity of coal and a 12 m heat source spacing on an equilateraltriangle pattern, calculations show that a heating period of about tenyears would be needed to raise an average temperature of coal to about350° C. Such a heating period may not be economically viable. Usingexperimental values for thermal conductivity and thermal diffusivity andthe same 12 m heat source spacing, calculations show that the heatingperiod to reach an average temperature of 350° C. would be about 3years. The elimination of about 7 years of heating a formation will inmany instances significantly improve the economic viability of an insitu conversion process for coal.

[0717] Molecular hydrogen has a relatively high thermal conductivity(e.g., the thermal conductivity of molecular hydrogen is about 6 timesthe thermal conductivity of nitrogen or air). Therefore it is believedthat as the amount of hydrogen in the formation void spaces increases,the thermal conductivity of the formation will also increase. Theincreases in thermal conductivity due to the presence of hydrogen in thevoid spaces somewhat offsets decreases in thermal conductivity caused bythe void spaces themselves. It is believed that increases in thermalconductivity due to the presence of hydrogen will be larger for coalformations as compared to other hydrocarbon containing formations sincethe amount of void spaces created during pyrolysis will be larger (coalhas a higher hydrocarbon density, so pyrolysis creates more void spacesin coal).

[0718] Hydrocarbon fluids were produced from a portion of a coalformation by an in situ experiment conducted in a portion of a coalformation. The coal was high volatile bituminous C coal. It was heatedwith electrical heaters. FIG. 98 illustrates a cross-sectional view ofthe in situ experimental field test system. As shown in FIG. 98, theexperimental field test system included at least coal formation 3802within the ground and grout wall 3800. Coal formation 3802 dipped at anangle of approximately 36° with a thickness of approximately 4.9 meters.FIG. 99 illustrates a location of heat sources 3804 a, 3804 b, 3804 c,production wells 3806 a, 3806 b, and temperature observation wells 3803a, 3808 b, 3808 c, 3808 d used for the experimental field test system.The three heat sources were disposed in a triangular configuration.Production well 3806 a was located proximate a center of the heat sourcepattern and equidistant from each of the heat sources. A secondproduction well 3806 b was located outside the heat source pattern andspaced equidistant from the two closest heat sources. Grout wall 3800was formed around the heat source pattern and the production wells. Thegrout wall may include pillars 1-24. Grout wall 3800 was configured toinhibit an influx of water into the portion during the in situexperiment. In addition, grout wall 3800 was configured to substantiallyinhibit loss of generated hydrocarbon fluids to an unheated portion ofthe formation.

[0719] Temperatures were measured at various times during the experimentat each of four temperature observation wells 3808 a, 3808 b, 3808 c,3808 d located within and outside of the heat source pattern asillustrated in FIG. 99. The temperatures measured (in degrees Celsius)at each of the temperature observation wells are displayed in FIG. 100as a function of time. Temperatures at observation wells 3808 a (3820),3808 b (3822), and 3808 c (3824) were relatively close to each other. Atemperature at temperature observation well 3808 d (3826) wassignificantly colder. This temperature observation well was locatedoutside of the heater well triangle illustrated in FIG. 99. This datademonstrates that in zones where there was little superposition of heattemperatures were significantly lower. FIG. 101 illustrated temperatureprofiles measured at the heat sources 3804 a (3830), 3804 b (3832), and3804 c (3834). The temperature profiles were relatively uniform at theheat sources.

[0720]FIG. 102 illustrates a plot of cumulative volume (m³) of liquidhydrocarbons produced 3840 as a function of time days). FIG. 111illustrates a plot of cumulative volume of gas produced 3910 in standardcubic feet, produced as a function of time (in days) for the same insitu experiment. Both FIG. 102 and FIG. 111 show the results during thepyrolysis stage only of the in situ experiment.

[0721]FIG. 103 illustrates the carbon number distribution of condensablehydrocarbons that were produced using the low temperature retortingprocess as described above. As can be seen in FIG. 103, relatively highquality products were produced during treatment. The results in FIG. 103are consistent with the results set forth in FIG. 108, which showresults from heating coal from the same formation in the laboratory forsimilar ranges of heating rates as were used in situ.

[0722] Table 5 illustrates the results from analyzing coal before andafter it was treated (including heating the temperatures set forth in asis set forth in FIG. 101 (i.e., after pyrolysis and production ofsynthesis gas) as described above. The coal was cored at about 11-11.3meters from the surface, midway into the coal bed, in both the “beforetreatment” and “after treatment” examples. Both cores were taken atabout the same location. Both cores were taken at about 0.66 meters fromwell 3804 c (between the grout wall and well 3804 c) in FIG. 99. In thefollowing Table 5 “FA” means Fisher Assay, “as rec'd” means the samplewas tested as it was received and without any further treatment,“Py-Water” means the water produced during pyrolysis, “H/C Atomic Ratio”means the atomic ratio of hydrogen to carbon, “daf” means “dry ashfree,” “dmmf” means “dry mineral matter free,” and “mmf” means “mineralmatter free.” The specific gravity of the “after treatment” core samplewas approximately 0.85 whereas the specific gravity of the “beforetreatment” core sample was approximately 1.35. TABLE 5 Before AnalysisTreatment After Treatment % Vitrinite Reflectance 0.54 5.16 FA (gal/ton,as-rec'd) 11.81 0.17 FA (wt %, as rec'd) 6.10 0.61 FA Py-Water (gal/ton,as-rec'd) 10.54 2.22 H/C Atomic Ratio 0.85 0.06 H (wt %, daf) 5.31 0.44O (wt %, daf) 17.08 3.06 N (wt %, daf) 1.43 1.35 Ash (wt %, as rec'd)32.72 56.50 Fixed Carbon (wt %, dmmf) 54.45 94.43 Volatile Matter (wt %,dmmf) 45.55 5.57 Heating Value (Btu/lb, moist, mmf) 12048 14281

[0723] Even though the cores were taken outside the areas within thetriangle formed by the three heaters in FIG. 99, nevertheless the coresdemonstrate that the coal remaining in the formation changedsignificantly during treatment. The vitrinite reflectance results shownin Table 5 demonstrate that the rank of the coal remaining in theformation changed substantially during treatment. The coal was a highvolatile bituminous C coal before treatment. After treatment, however,the coal was essentially anthracite. The Fischer Assay results shown inTable 5 demonstrate that most of the hydrocarbons in the coal had beenremoved during treatment. The H/C Atomic Ratio demonstrates that most ofthe hydrogen in the coal had been removed during treatment. Asignificant amount of nitrogen and ash was left in the formation.

[0724] In sum, the results shown in Table 5 demonstrate that asignificant amount of hydrocarbons and hydrogen were removed duringtreatment of the coal by pyrolysis and generation of synthesis gas.Significant amounts of undesirable products (ash and nitrogen) remain inthe formation, while the significant amounts of desirable products(e.g., condensable hydrocarbons and gas) were removed.

[0725]FIG. 104 illustrates a plot of weight percent of a hydrocarbonproduced versus carbon number distribution for two laboratoryexperiments on coal from the field experiment site. The coal was highvolatile bituminous C coal. As shown in FIG. 104, a carbon numberdistribution of fluids produced from a formation varied depending on,for example, pressure. For example, first pressure 3842 was about 1 barabsolute and second pressure 3844 was about 8 bars absolute. Thelaboratory carbon number distribution shown in FIG. 104 was similar tothat produced in the field experiment in FIG. 103 also at 1 barabsolute. As shown in FIG. 104, as pressure increased, a range of carbonnumbers of the hydrocarbon fluids decreased. An increase in productshaving carbon numbers less than 20 was observed when operating at 8 barsabsolute. Increasing the pressure from 1 bar absolute to 8 bars absolutealso increased an API gravity of the condensed hydrocarbon fluids. TheAPI gravities of condensed hydrocarbon fluids produced wereapproximately 23.1° and approximately 31.3°, respectively. Such anincrease in API gravity represents increased production of more valuableproducts.

[0726]FIG. 105 illustrates a bar graph of fractions from a boiling pointseparation of hydrocarbon liquids generated by a Fischer assay and aboiling point separation of hydrocarbon liquids from the coal cubeexperiment described herein (see, e.g., the system shown in FIG. 91).The experiment was conducted at a much slower heating rate (2 degreesCelsius per day) and the oil produced at a lower final temperature thanthe Fischer Assay. FIG. 105 shows the weight percent of various boilingpoint cuts of hydrocarbon liquids produced from a Fruitland highvolatile bituminous B coal. Different boiling point cuts may representdifferent hydrocarbon fluid compositions. The boiling point cutsillustrated include naphtha 3860 (initial boiling point to 166° C.), jetfuel 3862 (166° C. to 249° C.), diesel 3864 (249° C. to 370° C.), andbottoms 3866 (boiling point greater than 370° C.). The hydrocarbonliquids from the coal cube were substantially more valuable products.The API gravity of such hydrocarbon liquids was significantly greaterthan the API gravity of the Fischer Assay liquid. The hydrocarbonliquids from the coal cube also included significantly less residualbottoms than were produced from the Fischer Assay hydrocarbon liquids.

[0727]FIG. 106 illustrates a plot of percentage ethene, which is anolefin, to ethane produced from a coal formation as a function ofheating rate. Data points were derived from laboratory experimental data(see system shown in FIG. 74 and associated text) for slow heating ofhigh volatile bituminous C coal at atmospheric pressure, and fromFischer assay results. As illustrated in FIG. 106, the ratio of etheneto ethane increased as the heating rate increased. As such, it isbelieved that decreasing the heating rate of coal will decreaseproduction of olefins. The heating rate of a formation may be determinedin part by the spacings of heat sources within the formation, and by theamount of heat that is transferred from the heat sources to theformation.

[0728] Formation pressure may also have a significant effect on olefinproduction. A high formation pressure may tend to result in theproduction of small quantities of olefins. High pressure within aformation may result in a high H₂ partial pressure within the formation.The high H₂ partial pressure may result in hydrogenation of the fluidwithin the formation. Hydrogenation may result in a reduction of olefinsin a fluid produced from the formation. A high pressure and high H₂partial pressure may also result in inhibition of aromatization ofhydrocarbons within the formation. Aromatization may include formationof aromatic and cyclic compounds from alkanes and/or alkenes within ahydrocarbon mixture. If it is desirable to increase production ofolefins from a formation, the olefin content of fluid produced from theformation may be increased by reducing pressure within the formation.The pressure may be reduced by drawing off a larger quantity offormation fluid from a portion of the formation that is being produced.The pressure may be reduced by drawing a vacuum on the portion of theformation being produced.

[0729] The system depicted in FIG. 74, and the method of using suchsystem, was used to conduct experiments on high volatile bituminous Ccoal when such coal was heated at 5° C./day at atmospheric pressure.FIG. 76 depicts certain data points from such experiment (the linedepicted in FIG. 76 was produced from a linear regression analysis ofsuch data points). FIG. 76 illustrates the ethene to ethane molar ratioas a function of hydrogen molar concentration in non-condensablehydrocarbons produced from the coal during the experiment. The ethene toethane ratio in the non-condensable hydrocarbons is reflective of olefincontent in all hydrocarbons produced from the coal. As can be seen inFIG. 76, as the concentration of hydrogen autogenously increased duringpyrolysis, the ratio of ethene to ethane decreased. It is believed thatincreases in the concentration (and partial pressure) of hydrogen duringpyrolysis causes the olefin concentration to decrease in the fluidsproduced from pyrolysis.

[0730]FIG. 107 illustrates product quality, as measured by API gravity,as a function of rate of temperature increase of fluids produced fromhigh volatile bituminous “C” coal. Data points were derived from Fischerassay data and from laboratory experiments. For the Fischer assay data,the rate of temperature increase was approximately 17,100° C./day andthe resulting API gravity was less than 11°. For the relatively slowlaboratory experiments, the rate of temperature increase ranged fromabout 2° C./day to about 10° C./day, and the resulting API gravitiesranged from about 23° to about 26°. A substantially linear decrease inquality (decrease in API gravity) was exhibited as the logarithmicheating rate increased.

[0731]FIG. 108 illustrates weight percentages of various carbon numbersproducts removed from high volatile bituminous “C” coal when coal isheated at various heating rates. Data points were derived fromlaboratory experiments and a Fischer assay. Curves for heating at a rateof 2° C./day 3870, 3° C./day 3872, 5° C./day 3874, and 10° C./day 3876provided for similar carbon number distributions in the produced fluids.A coal sample was also heated in a Fisher assay test at a rate of about17,100° C./day. The data from the Fischer assay test is indicated byreference numeral 3878. Slow heating rates resulted in less productionof components having carbon numbers greater than 20 as compared to theFischer assay results 3878. Lower heating rates also produced higherweight percentages of components with carbon numbers less than 20. Thelower heating rates produced large amounts of components having carbonnumbers near 12. A peak in carbon number distribution near 12 is typicalof the in situ conversion process for coal.

[0732] An experiment was conducted on the coal formation treatedaccording to the in situ conversion process to measure the uniformpermeability of the formation after pyrolysis. After heating a portionof the coal formation, a ten minute pulse of CO₂ was injected into theformation at first production well 3806 a and produced at well 3804 a,as shown in FIG. 99. The CO₂ tracer test was repeated from productionwell 3806 a to well 3804 b and from production well 3806 a to well 3804c. As described above, each of the three different heat sources werelocated equidistant from the production well. The CO₂ was injected at arate of 4.08 m³/hr (144 standard cubic feet per hour). As illustrated inFIG. 109, the CO₂ reached each of the three different heat sources atapproximately the same time. Line 3900 illustrates production of CO₂ atheat source 3804 a, line 3902 illustrates production of CO₂ at heatsource 3804 b, and line 3904 illustrates production of CO₂ at heatsource 3804 c. As shown in FIG. 111, yield of CO₂ from each of the threedifferent wells was also approximately equal over time. Suchapproximately equivalent transfer of a tracer pulse of CO₂ through theformation and yield of CO₂ from the formation indicated that theformation was substantially uniformly permeable. The fact that the firstCO₂ arrival only occurs approximately 18 minutes after start of the CO₂pulse indicates that no preferential paths had been created between well3806 a and 3804 a, 3804 b, and 3804 c.

[0733] The in situ permeability was measured by injecting a gas betweendifferent wells after the pyrolysis and synthesis gas formation stageswere complete. The measured permeability varied from about 4.5 darcy to39 darcy (with an average of about 20 darcy), thereby indicating thatthe permeability was high and relatively uniform. The before-treatmentpermeability was only about 50 millidarcy.

[0734] Synthesis gas was also produced in an in situ experiment from theportion of the coal containing formation shown in FIG. 98 and FIG. 99.In this experiment, heater wells were also configured to inject fluids.FIG. 110 is a plot of weight of produced volatiles (oil andnoncondensable gas) in kilograms as a function of cumulative energyinput in kilowatt hours with regard to the in situ experimental fieldtest. The figure illustrates the quantity of pyrolysis fluids andsynthesis gas produced from the formation.

[0735]FIG. 112 is a plot of the volume of oil equivalent produced (m³)as a function of energy input into the coal formation (kW·hr) from theexperimental field test. The volume of oil equivalent in cubic meterswas determined by converting the energy content of the volume ofproduced oil plus gas to a volume of oil with the same energy content.

[0736] The start of synthesis gas production, indicated by arrow 3912,was at an energy input of approximately 77,000 kW·hr. The average coaltemperature in the pyrolysis region had been raised to 620° C. Becausethe average slope of the curve in FIG. 112 in the pyrolysis region isgreater than the average slope of the curve in the synthesis gas region,FIG. 112 illustrates that the amount of useable energy contained in theproduced synthesis gas is less than that contained in the pyrolysisfluids. Therefore, synthesis gas production is less energy efficientthan pyrolysis. There are two reasons for this result. First, the two H₂molecules produced in the synthesis gas reaction have a lower energycontent than low carbon number hydrocarbons produced in pyrolysis.Second, the endothermic synthesis gas reaction consumes energy.

[0737]FIG. 113 is a plot of the total synthesis gas production (m³/min)from the coal formation versus the total water inflow (kg/hr) due toinjection into the formation from the experimental field test resultsfacility. Synthesis gas may be generated in a formation at a synthesisgas generating temperature before the injection of water or steam due tothe presence of natural water inflow into hot coal formation. Naturalwater may come from below the formation.

[0738] From FIG. 113, the maximum natural water inflow is approximately5 kg/h as indicated by arrow 3920. Arrows 3922, 3924, and 3926 representinjected water rates of about 2.7 kg/hr, 5.4 kg/hr, and 11 kg/hr,respectively, into central well 3806 a. Production of synthesis gas isat heater wells 3804 a, 3804 b, and 3804 c. FIG. 113 shows that thesynthesis gas production per unit volume of water injected decreases atarrow 3922 at approximately 2.7 kg/h of injected water or 7.7 kg/hr oftotal water inflow. The reason for the decrease is that steam is flowingtoo fast through the coal seam to allow the reactions to approachequilibrium conditions.

[0739]FIG. 114 illustrates production rate of synthesis gas (m³/min) asa function of steam injection rate (kg/h) in a coal formation. Data 3930for a first run corresponds to injection at producer well 3806 a in FIG.99, and production of synthesis gas at heater wells 3804 a, 3804 b, and3804 c. Data 3932 for a second run corresponds to injection of steam atheater well 3804 c, and production of additional gas at a productionwell 3806 a. Data 3930 for the first run corresponds to the data shownin FIG. 113. As shown in FIG. 114, the injected water is in reactionequilibrium with the formation to about 2.7 kg/hr of injected water. Thesecond run results in substantially the same amount of additionalsynthesis gas produced, shown by data 3932, as the first run to about1.2 kg/hr of injected steam. At about 1.2 kg/hr, data 3930 starts todeviate from equilibrium conditions because the residence time isinsufficient for the additional water to react with the coal. Astemperature is increased, a greater amount of additional synthesis gasis produced for a given injected water rate. The reason is that athigher temperatures the reaction rate and conversion of water intosynthesis gas increases.

[0740]FIG. 115 is a plot that illustrates the effect of methaneinjection into a heated coal formation in the experimental field test(all of the units in FIGS. 115-118 are in m³ per hour). FIG. 115demonstrates hydrocarbons added to the synthesis gas producing fluid arecracked within the formation. FIG. 99 illustrates the layout of theheater and production wells at the field test facility. Methane wasinjected into production wells 3806 a and 3806 b and fluid was producedfrom heater wells 3804 a, 3804 b, and 3804 c. The average temperaturesmeasured at various wells were as follows: 3804 a (746° C.), 3804b (746°C.), 3804 c (767° C.), 3808 a (592° C.), 3808 b (573° C.), 3808 c (606°C.), and 3806 a (769° C.). When the methane contacted the formation, itcracked within the formation to produce H₂ and coke. FIG. 115 shows thatas the methane injection rate increased, the production of H₂ 3940increased. This indicated that methane was cracking to form H₂. Methaneproduction 3942 also increased which indicates that not all of theinjected methane is cracked. The measured compositions of ethane,ethene, propane, and butane were negligible.

[0741]FIG. 116 is a plot that illustrates the effect of ethane injectioninto a heated coal formation in the experimental field test. Ethane wasinjected into production wells 3806 a and 3806 b and fluid was producedfrom heater wells 3804 a, 3804 b, and 3804 c. The average temperaturesmeasured at various wells were as follows: 3804 a (742° C.), 3804b (750°C.), 3804 c (744° C.), 3808 a (611° C.), 3808 b (595° C.), 3808 c (626°C.), and 3806 a (818° C.). When ethane contacted the formation, itcracked to produce H₂, methane, ethene, and coke. FIG. 116 shows that asthe ethane injection rate increased, the production of H₂ 3950, methane3952, ethane 3954, and ethene 3956 increased. This indicates that ethaneis cracking to form H₂ and low molecular weight hydrocarbons. Theproduction rate of higher carbon number products (i.e., propane andpropylene) were unaffected by the injection of ethane.

[0742]FIG. 117 is a plot that illustrates the effect of propaneinjection into a heated coal formation in the experimental field test.Propane was injected into production wells 3806 a and 3806 b and fluidwas produced from heater wells 3804 a, 3804 b, and 3804 c. The averagetemperatures measured at various wells were as follows: 3804 a (737°C.), 3804 b (753° C.), 3804 c (726° C.), 3808 a (589° C.), 3808 b (573°C.), 3808 c (606° C.), and 3806 a (769° C.). When propane contacted theformation, it cracked to produce H₂, methane, ethane, ethene, propyleneand coke. FIG. 117 shows that as the propane injection rate increased,the production of H2 3960, methane 3962, ethane 3964, ethene 3966,propane 3968, and propylene 3969 increased. This indicates that propaneis cracking to form H₂ and lower molecular weight components.

[0743]FIG. 118 is a plot that illustrates the effect of butane injectioninto a heated coal formation in the experimental field test. Butane wasinjected into production wells 3806 a and 3806 b and fluid was producedfrom heater wells 3804 a, 3804 b, and 3804 c. The average temperaturemeasured at various wells were as follows: 3804 a (772° C.), 3804 b(764° C.), 3804 c (753° C.), 3808 a (650° C.), 3808 b (591° C.), 3808 c(624° C.), and 3806 a (830° C.). When butane contacted the formation, itcracked to produce H₂, methane, ethane, ethene, propane, propylene, andcoke. FIG. 118 shows that as the butane injection rate increased, theproduction of H2 3970, methane 3972, ethane 3974, ethene 3976, propane3978, and propylene 3979 increased. This indicates that butane iscracking to form H₂ and lower molecular weight components.

[0744]FIG. 119 is a plot of the composition of gas (in volume percent)produced from the heated coal formation versus time in days at theexperimental field test. The species compositions included 3980—methane,3982—H₂, 3984—carbon dioxide, 3986—hydrogen sulfide, and 3988—carbonmonoxide. FIG. 119 shows a dramatic increase in the H₂ 3982concentration after about 150 days, or when synthesis gas productionbegan.

[0745]FIG. 120 is a plot of synthesis gas conversion versus time forsynthesis gas generation runs in the experimental field test performedon separate days. The temperature of the formation was about 600° C. Thedata demonstrates initial uncertainty in measurements in the oil/waterseparator. Synthesis gas conversion consistently approached a conversionof between about 40% and 50% after about 2 hours of synthesis gasproducing fluid injection.

[0746] Table 6 includes a composition of synthesis gas producing duringa run of the in situ coal field experiment. TABLE 6 Component Mol % Wt %Methane 12.263 12.197 Ethane 0.281 0.525 Ethene 0.184 0.320 Acetylene0.000 0.000 Propane 0.017 0.046 Propylene 0.026 0.067 Propadiene 0.0010.004 Isobutane 0.001 0.004 n-Butane 0.000 0.001 1-Butene 0.001 0.003Isobutene 0.000 0.000 cis-2-Butene 0.005 0.018 trans-2-Butene 0.0010.003 1,3-Butadiene 0.001 0.005 Isopentane 0.001 0.002 n-Pentane 0.0000.002 Pentene-1 0.000 0.000 T-2-Pentene 0.000 0.000 2-Methyl-2-Butene0.000 0.000 C-2-Pentene 0.000 0.000 Hexanes 0.081 0.433 H₂ 51.247 6.405Carbon monoxide 11.556 20.067 Carbon dioxide 17.520 47.799 Nitrogen5.782 10.041 Oxygen 0.955 1.895 Hydrogen sulfide 0.077 0.163 Total100.000 100.000

[0747] The experiment was performed in batch oxidation mode at about620° C. The presence of nitrogen and oxygen is due to contamination ofthe sample with air. The mole percent of H₂, carbon monoxide, and carbondioxide, neglecting the composition of all other species, may bedetermined for the above data. For example, mole percent of H₂, carbonmonoxide, and carbon dioxide may be increased proportionally such thatthe mole percentages of the three components equals approximately 100%.In this manner, the mole percent of H₂, carbon monoxide, and carbondioxide, neglecting the composition of all other species, were 63.8%,14.4%, and 21.8%, respectively. The methane is believed to comeprimarily from the pyrolysis region outside the triangle of heaters.These values are in substantial agreement with the results ofequilibrium calculations shown in FIG. 121.

[0748]FIG. 121 is a plot of calculated equilibrium gas dry molefractions for a coal reaction with water. Methane reactions are notincluded for FIGS. 121-122. The fractions are representative of asynthesis gas that has been produced from a coal formation and has beenpassed through a condenser to remove water from the produced gas.Equilibrium gas dry mole fractions are shown in FIG. 121 for H₂ 4000,carbon monoxide 4002, and carbon dioxide 4004 as a function oftemperature at a pressure of 2 bar absolute. As shown in FIG. 121, at390° C., liquid production tends to cease, and production of gases tendsto commence. The gases produced at this temperature include about 67%H₂, and about 33% carbon dioxide. Carbon monoxide is present innegligible quantities below about 410° C. At temperatures of about 500°C., however, carbon monoxide is present in the produced gas inmeasurable quantities. For example, at 500° C., about 66.5% H₂, about32% carbon dioxide, and about 2.5% carbon monoxide are present. At 700°C., the produced gas includes about 57.5% H₂, about 15.5% carbondioxide, and about 27% carbon monoxide.

[0749]FIG. 122 is a plot of calculated equilibrium wet mole fractionsfor a coal reaction with water. Equilibrium wet mole fractions are shownfor water 4006, H₂ 4008, carbon monoxide 4010, and carbon dioxide 4012as a function of temperature at a pressure of 2 bar absolute. At 390°C., the produced gas includes about 89% water, about 7% H₂, and about 4%carbon dioxide. At 500° C., the produced gas includes about 66% water,about 22% H₂, about 11% carbon dioxide, and about 1% carbon monoxide. At700° C., the produced gas include about percent 18% water, about 47.5%H₂, about 12% carbon dioxide, and about 22.5% carbon monoxide.

[0750]FIG. 121 and FIG. 122 illustrate that at the lower end of thetemperature range at which synthesis gas may be produced (i.e., about400° C.) equilibrium gas phase fractions may not favor production of H₂within a formation. As temperature increases, the equilibrium gas phasefractions increasingly favor the production of H₂. For example, as shownin FIG. 122, the gas phase equilibrium wet mole fraction of H₂ increasesfrom about 9% at 400° C. to about 39% at 610° C. and reaches 50% atabout 800° C. FIG. 121 and FIG. 122 further illustrate that attemperatures greater than about 660° C., equilibrium gas phase fractionstend to favor production of carbon monoxide over carbon dioxide.

[0751]FIG. 121 and FIG. 122 illustrate that as the temperature increasesfrom between about 400° C. to about 1000° C., the H₂ to carbon monoxideratio of produced synthesis gas may continuously decrease throughoutthis range. For example, as shown in FIG. 122, the equilibrium gas phaseH₂ to carbon monoxide ratio at 500° C., 660° C., and 1000° C. is about22:1, about 3:1, and about 1:1, respectively. FIG. 122 also indicatesthat produced synthesis gas at lower temperatures may have a largerquantity of water and carbon dioxide than at higher temperatures. As thetemperature increases, the overall percentage of carbon monoxide andhydrogen within the synthesis gas may increase.

[0752]FIG. 123 is a flowchart of an example of a pyrolysis stage 4020and synthesis gas production stage 4022 with heat and mass balances inhigh volatile type A or B bituminous coal. In the pyrolysis stage 4020,heat 4024 is supplied to the coal formation 4026. Liquid and gasproducts 4028 and water 4030 exit the formation 4026. The portion of theformation subjected to pyrolysis is composed substantially of char afterundergoing pyrolysis heating. Char refers to a solid carbonaceousresidue that results from pyrolysis of organic material. In thesynthesis gas production stage 4022, steam 4032 and heat 4034 aresupplied to formation 4036 that has undergone pyrolysis and synthesisgas 4038 is produced.

[0753] In the embodiments in FIGS. 124-126 the methane reactions inEquations (4) and (5) are included. The calculations set forth hereinassume that char is only made of carbon and that there is an excess ofcarbon to steam. About 890 MWe of energy 4024 is required to pyrolyzeabout 105,800 metric tons per day of coal. The pyrolysis products 4028include liquids and gases with a production of 23,000 cubic meters perday. The pyrolysis process also produces about 7,160 metric tons per dayof water 4030. In the synthesis gas stage about 57,800 metric tons perday of char with injection of 23,000 metric tons per day of steam 4032and 2,000 MWe of energy 4034 with a 20% conversion will produce 12,700cubic meters equivalent oil per day of synthesis gas 4038.

[0754]FIG. 124 is an example of a low temperature in situ synthesis gasproduction that occurs at a temperature of about 450° C. with heat andmass balances in a coal formation that was previously pyrolyzed. A totalof about 42,900 metric tons per day of water is injected into formation4100 which may be char. FIG. 124 illustrates that a portion of water4102 at 25° C. is injected directly into the formation 4100. A portionof water 4102 is converted into steam 4104 at a temperature of about130° C. and a pressure at about 3 bar absolute using about 1227 MWe ofenergy 4106 and injected into formation 4100. A portion of the remainingsteam may be converted into steam 4108 at a temperature of about 450° C.and a pressure at about 3 bar absolute using about 318 MWe of energy4110. The synthesis gas production involves about 23% conversion of13,137 metric tons per day of char to produce 56.6 millions of cubicmeters per day of synthesis gas with an energy content of 5,230 MW.About 238 MW of energy 4112 is supplied to formation 4100 to account forthe endothermic heat of reaction of the synthesis gas reaction. Theproduct stream 4114 of the synthesis gas reaction includes 29,470 metrictons per day of water at 46 volume percent, 501 metric tons per daycarbon monoxide at 0.7 volume percent, 540 tons per day H₂ at 10.7volume percent, 26,455 metric tons per day carbon dioxide at 23.8 volumepercent, and 7,610 metric tons per day methane at 18.8 volume percent.

[0755]FIG. 125 is an example of a high temperature in situ synthesis gasproduction that occurs at a temperature of about 650° C. with heat andmass balances in a coal formation that was previously pyrolyzed. A totalof about 34,352 metric tons per day of water is injected into formation4200. FIG. 125 illustrates that a portion of water 4202 at 25° C. isinjected directly into formation 4200. A portion of water 4202 isconverted into steam 4204 at a temperature of about 130° C. and apressure at about 3 bar absolute using about 982 MWe of energy 4206, andinjected into formation 4200. A portion of the remaining steam isconverted into steam 4208 at a temperature of about 650° C. and apressure at about 3 bar absolute using about 413 MWe of energy 4210. Thesynthesis gas production involves about 22% conversion of 12,771 metrictons per day of char to produce 56.6 millions of cubic meters per day ofsynthesis gas with an energy content of 5,699 MW. About 898 MW of energy4212 is supplied to formation 4200 to account for the endothermic heatof reaction of the synthesis gas reaction. The product stream 4214 ofthe synthesis gas reaction includes 10,413 metric tons per day of waterat 22.8 volume percent, 9,988 metric tons per day carbon monoxide at14.1 volume percent, 1771 metric tons per day H₂ at 35 volume percent,21,410 metric tons per day carbon dioxide at 19.3 volume percent, and3535 metric tons per day methane at 8.7 volume percent.

[0756]FIG. 126 is an example of an in situ synthesis gas production in acoal formation with heat and mass balances. Synthesis gas generatingfluid that includes water 4302 is supplied to the formation 4300. Atotal of about 22,000 metric tons per day of water is required for a lowtemperature process and about 24,000 metric tons per day is required fora high temperature process. A portion of the water may be introducedinto the formation as steam. Steam 4304 is produced by supplying heat tothe water from an external source. About 7,119 metric tons per day ofsteam is provided for the low temperature process and about 6913 metrictons per day of steam is provided for the high temperature process.

[0757] At least a portion of the aqueous fluid 4306 exiting formation4300 is recycled 4308 back into the formation for generation ofsynthesis gas. For a low temperature process about 21,000 metric tonsper day of aqueous fluids is recycled and for a high temperature processabout 10,000 metric tons per day of aqueous fluids is recycled. Theproduced synthesis gas 4310 includes carbon monoxide, H₂, and methane.The produced synthesis gas has a heat content of about 430,000 MMBtu perday for a low temperature process and a heat content of about 470,000MMBtu per day for a low temperature process. Carbon dioxide 4312produced in the synthesis gas process includes about 26,500 metric tonsper day in the low temperature process and about 21,500 metric tons perday in the high temperature process. At least a portion of the producedsynthesis gas 4310 is used for combustion to heat the formation. Thereis about 7,119 metric tons per day of carbon dioxide in the steam 4308for the low temperature process and about 6,913 metric tons per day ofcarbon dioxide in the steam for the high temperature process. There isabout 2,551 metric tons per day of carbon dioxide in a heat reservoirfor the low temperature process and about 9,628 metric tons per day ofcarbon dioxide in a heat reservoir for the high temperature process.There is about 14,571 metric tons per day of carbon dioxide in thecombustion of synthesis gas for the low temperature process and about18,503 metric tons per day of carbon dioxide in produced combustionsynthesis gas for the high temperature process. The produced carbondioxide has a heat content of about 60 gigajoules (“GJ”) per metric tonfor the low temperature process and about 6.3 GJ per metric ton for thehigh temperature process.

[0758] Table 7 is an overview of the potential production volume ofapplications of synthesis gas produced by wet oxidation. The estimatesare based on 56.6 million standard cubic meters of synthesis gasproduced per day at 700° C. TABLE 7 Production (main Applicationproduct) Power  2,720 Megawatts Hydrogen  2,700 metric tons/day NH₃13,800 metric tons/day CH₄  7,600 metric tons/day Methanol 13,300 metrictons/day Shell Middle  5,300 metric tons/day Distillates

[0759] Experimental adsorption data has demonstrated that carbon dioxidemay be stored in coal that has been pyrolyzed. FIG. 127 is a plot of thecumulative adsorbed methane and carbon dioxide in cubic meters permetric ton versus pressure in bar absolute at 25° C. on coal. The coalsample is sub-bituminous coal from Gillette, Wyo. Data sets 4401, 4402,4403, 4404, and 4405 are for carbon dioxide adsorption on a posttreatment coal sample that has been pyrolyzed and has undergonesynthesis gas generation. Data set 4406 is for adsorption on anunpyrolyzed coal sample from the same formation. Data set 4401 isadsorption of methane at 25° C. Data sets 4402, 4403, 4404, and 4405 areadsorption of carbon dioxide at 25° C., 50° C., 100° C., and 150° C.,respectively. Data set 4406 is adsorption of carbon dioxide at 25° C. onthe unpyrolyzed coal sample. FIG. 127 shows that carbon dioxide attemperatures between 25° C. and 100° C. is more strongly adsorbed thanmethane at 25° C. in the pyrolyzed coal. FIG. 127 demonstrates that acarbon dioxide stream passed through post treatment coal tends todisplace methane from the post treatment coal.

[0760] Computer simulations have demonstrated that carbon dioxide may besequestered in both a deep coal formation and a post treatment coalformation. The Comet2 Simulator determined the amount of carbon dioxidethat could be sequestered in a San Juan Basin type deep coal formationand a post treatment coal formation. The simulator also determined theamount of methane produced from the San Juan Basin type deep coalformation due to the carbon dioxide injection. The model employed forboth the deep coal formation and the post treatment coal formation was a1.3 km² area, with a repeating 5 spot well pattern. The 5 spot wellpattern included four injection wells arranged in a square and oneproduction well at the center of the square. The properties of the SanJuan Basin and the post treatment coal formations are shown in Table 8.Additional details of simulations of carbon dioxide sequestration indeep coal formations and comparisons with field test results may befound in Pilot Test Demonstrates How Carbon Dioxide Enhances Coal BedMethane Recovery, Lanny Schoeling and Michael McGovern, PetroleumTechnology Digest, September 2000, p. 14-15. TABLE 8 Post treatment DeepCoal coal Formation formation (San Juan Basin) (Post pyrolysis process)Coal Thickness (m)  9  9 Coal Depth (m) 990 460 Initial Pressure (barsabs.) 114  2 Initial Temperature 25° C. 25° C. Permeability (md) 5.5(horiz.), 10,000 (horiz.), 0 (vertical) 0 (vertical) Cleat porosity 0.2%40%

[0761] The simulation model accounts for the matrix and dual porositynature of coal and post treatment coal. For example, coal and posttreatment coal are composed of matrix blocks. The spaces between theblocks are called “cleats”. Cleat porosity is a measure of availablespace for flow of fluids in the formation. The relative permeabilitiesof gases and water within the cleats required for the simulation werederived from field data from the San Juan coal. The same values forrelative permeabilities were used in the post treatment coal formationsimulations. Carbon dioxide and methane were assumed to have the samerelative permeability.

[0762] The cleat system of the deep coal formation was modeled asinitially saturated with water. Relative permeability data for carbondioxide and water demonstrate that high water saturation inhibitsabsorption of carbon dioxide within cleats. Therefore, water is removedfrom the formation before injecting carbon dioxide into the formation.

[0763] In addition, the gases within the cleats may adsorb in the coalmatrix. The matrix porosity is a measure of the space available forfluids to adsorb in the matrix. The matrix porosity and surface areawere taken into account with experimental mass transfer and isothermadsorption data for coal and post treatment coal. Therefore, it is notnecessary to specify a value of the matrix porosity and surface area inthe model.

[0764] The preferential adsorption of carbon dioxide over methane onpost treatment coal was incorporated into the model based onexperimental adsorption data. For example, FIG. 127 demonstrates thatcarbon dioxide has a significantly higher cumulative adsorption thanmethane over an entire range of pressures at a specified temperature.Once the carbon dioxide enters in the cleat system, methane diffuses outof and desorbs off the matrix. Similarly, carbon dioxide diffuses intoand adsorbs onto the matrix. In addition, FIG. 127 also shows carbondioxide may have a higher cumulative adsorption on a pyrolyzed coalsample than an unpyrolyzed coal.

[0765] The pressure-volume-temperature (PVT) properties and viscosityrequired for the model were taken from literature data for the purecomponent gases.

[0766] The simulation modeled a sequestration process over a time periodof about 3700 days for the deep coal formation model. Removal of thewater in the coal formation was simulated by production from all fivewells. The production rate of water was about 40 m³/day for about thefirst 370 days. The production rate of water decreased significantlyafter the first 370 days. It continued to decrease through the remainderof the simulation run to about zero at the end. Carbon dioxide injectionwas started at approximately 370 days at a flow rate of about 113,000standard (in this context “standard” means 1 atmosphere pressure and15.5 degrees Celsius) m³/day. The injection rate of carbon dioxide wasdoubled to about 226,000 standard m³/day at approximately 1440 days. Theinjection rate remained at about 226,000 standard m³/day until the endof the simulation run.

[0767]FIG. 130 illustrates the pressure at the wellhead of the injectionwells as a function of time during the simulation. The pressuredecreased from 114 bars absolute to about 20 bars absolute over thefirst 370 days. The decrease in the pressure was due to removal of waterfrom the coal formation. Pressure then started to increase substantiallyas carbon dioxide injection started at 370 days. The pressure reached amaximum of 98 bars. The pressure then began to gradually decrease after480 days. At about 1440 days, the pressure increased again to about 143bars absolute due to the increase in the carbon dioxide injection rate.The pressure gradually increased until about 3640 days. The pressurejumped at about 3640 days because the production well was closed off.

[0768]FIG. 131 illustrates the production rate of carbon dioxide 5060and methane 5070 as a function of time in the simulation. FIG. 131 showsthat carbon dioxide was produced at a rate between about 0-10,000 m³/dayduring approximately the first 2400 days. The production rate of carbondioxide was significantly below the injection rate. Therefore, thesimulation predicts that most of the injected carbon dioxide is beingsequestered in the coal formation. However, at about 2400 days, theproduction rate of carbon dioxide started to rise significantly due toonset of saturation of the coal formation.

[0769] In addition, FIG. 131 shows that methane was desorbing as carbondioxide was adsorbing in the coal formation. Between about 370-2400days, the methane production rate 5070 increased from about 60,000 toabout 115,000 standard m³/day. The increase in the methane productionrate between about 1440-2400 days was caused by the increase in carbondioxide injection rate at about 1440 days. The production rate ofmethane started to decrease after about 2400 days. This was due to thesaturation of the coal formation. The simulation predicted a 50%breakthrough at about 2700 days. “Breakthrough” is defined as the ratioof the flow rate of carbon dioxide to the total flow rate of the totalproduced gas times 100%. Also, the simulation predicted about a 90%breakthrough at about 3600 days.

[0770]FIG. 132 illustrates cumulative methane produced 5090 and thecumulative net carbon dioxide injected 5080 as a function of time duringthe simulation. The cumulative net carbon dioxide injected is the totalcarbon dioxide produced subtracted from the total carbon dioxideinjected. FIG. 132 shows that by the end of the simulated injectionabout twice as much carbon dioxide was stored than methane produced. Inaddition, the methane production was about 0.24 billion standard m³ at50% carbon dioxide breakthrough. Also, the carbon dioxide sequestrationwas about 0.39 billion standard m³ at 50% carbon dioxide breakthrough.The methane production was about 0.26 billion standard m³ at 90% carbondioxide breakthrough. Also, the carbon dioxide sequestration was about0.46 billion standard m³ at 90% carbon dioxide breakthrough.

[0771] Table 8 shows that the permeability and porosity of thesimulation in the post treatment coal formation were both significantlyhigher than in the deep coal formation prior to treatment. Also, theinitial pressure was much lower. The depth of the post treatment coalformation was shallower than the deep coal bed methane formation. Thesame relative permeability data and PVT data used for the deep coalformation were used for the coal formation simulation. The initial watersaturation for the post treatment coal formation was set at 70%. Waterwas present because it is used to cool the hot spent coal formation to25° C. The amount of methane initially stored in the post treatment coalis very low.

[0772] The simulation modeled a sequestration process over a time periodof about 3800 days for the post treatment coal formation model. Thesimulation modeled removal of water from the post treatment coalformation with production from all five wells. During about the first200 days, the production rate of water was about 680,000 standardm³/day. From about 200-3300 days the water production rate was betweenabout 210,000 to about 480,000 standard m³/day. Production rate of waterwas negligible after about 3300 days. Carbon dioxide injection wasstarted at approximately 370 days at a flow rate of about 113,000standard m³/day. The injection rate of carbon dioxide was increased toabout 226,000 standard m³/day at approximately 1440 days. The injectionrate remained at 226,000 standard m³/day until the end of the simulatedinjection.

[0773]FIG. 133 illustrates the pressure at the wellhead of the injectionwells as a function of time during the simulation of the post treatmentcoal formation model. The pressure was relatively constant up to about370 days. The pressure increased through most of the rest of thesimulation run up to about 36 bars absolute. The pressure rose steeplystarting at about 3300 days because the production well was closed off.

[0774]FIG. 134 illustrates the production rate of carbon dioxide as afunction of time in the simulation of the post treatment coal formationmodel. FIG. 134 shows that the production rate of carbon dioxide wasalmost negligible during approximately the first 2200 days. Therefore,the simulation predicts that nearly all of the injected carbon dioxideis being sequestered in the post treatment coal formation. However, atabout 2240 days, the produced carbon dioxide began to increase. Theproduction rate of carbon dioxide started to rise significantly due toonset of saturation of the post treatment coal formation.

[0775]FIG. 135 illustrates cumulative net carbon dioxide injected as afunction of time during the simulation in the post treatment coalformation model. The cumulative net carbon dioxide injected is the totalcarbon dioxide produced subtracted from the total carbon dioxideinjected. FIG. 135 shows that the simulation predicts a potential netsequestration of carbon dioxide of 0.56 Bm³. This value is greater thanthe value of 0.46 Bm³ at 90% carbon dioxide breakthrough in the deepcoal formation. However, comparison of FIG. 130 with FIG. 133 shows thatsequestration occurs at much lower pressures in the post treatment coalformation model. Therefore, less compression energy was required forsequestration in the post treatment coal formation.

[0776] The simulations show that large amounts of carbon dioxide may besequestered in both deep coal formations and in post treatment coalformations that have been cooled.

[0777] Carbon dioxide may be sequestered in the post treatment coalformation, in coal formations that have not been pyrolyzed, and/or inboth types of formations.

[0778]FIG. 128 is a flowchart of an embodiment of an in situ synthesisgas production process integrated with a SMDS Fischer-Tropsch and waxcracking process with heat and mass balances. The synthesis gasgenerating fluid injected into the formation includes about 24,000metric tons per day of water 4530, which includes about 5,500 metrictons per day of water 4540 recycled from the SMDS Fischer-Tropsch andwax cracking process 4520. A total of about 1700 MW of energy issupplied to the in situ synthesis gas production process. About 1020 MWof energy 4535 of the approximately 1700 MW of energy is supplied by insitu reaction of an oxidizing fluid with the formation, andapproximately 680 MW of energy 4550 is supplied by the SMDSFischer-Tropsch and wax cracking process 4520 in the form of steam.About 12,700 cubic meters equivalent oil per day of synthesis gas 4560is used as feed gas to the SMDS Fischer-Tropsch and wax cracking process4520. The SMDS Fischer-Tropsch and wax cracking process 4520 producesabout 4,770 cubic meters per day of products 4570 that may includenaphtha, kerosene, diesel, and about 5,880 cubic meters equivalent oilper day of off gas 4580 for a power generation facility.

[0779]FIG. 129 is a comparison between numerical simulation and the insitu experimental coal field test composition of synthesis gas producedas a function of time. The plot excludes nitrogen and traces of oxygenthat were contaminants during gas sampling. Symbols representexperimental data and curves represent simulation results. Hydrocarbons4601 are methane since all other heavier hydrocarbons have decomposed atthe prevailing temperatures. The simulation results are moving averagesof raw results, which exhibit peaks and troughs of approximately ±10percent of the averaged value. In the model, the peaks of H₂ occurredwhen fluids were injected into the coal seam, and coincided with lows inCO₂ and CO.

[0780] The simulation of H₂ 4604 provides a good fit to observedfraction of H₂ 4603. The simulation of methane 4602 provides a good fitto observed fraction of methane 4601. The simulation of carbon dioxide4606 provides a good fit to observed fraction of carbon dioxide 4605.The simulation of CO 4608 overestimated the fraction of CO 4607 by 4-5percentage points. Carbon monoxide is the most difficult of thesynthesis gas components to model. Also, the carbon monoxide discrepancymay be due to fact that the pattern temperatures exceeded the 550° C.,the upper limit at which the numerical model was calibrated.

[0781] Other methods of producing synthesis gas were successfullydemonstrated at the experimental field test. These included continuousinjection of steam and air, steam and oxygen, water and air, water andoxygen, steam, air and carbon dioxide. All these injections successfullygenerated synthesis gas in the hot coke formation.

[0782] Further modifications and alternative embodiments of variousaspects of the invention may be apparent to those skilled in the art inview of this description. Accordingly, this description is to beconstrued as illustrative only and is for the purpose of teaching thoseskilled in the art the general manner of carrying out the invention. Itis to be understood that the forms of the invention shown and describedherein are to be taken as the presently preferred embodiments. Elementsand materials may be substituted for those illustrated and describedherein, parts and processes may be reversed, and certain features of theinvention may be utilized independently, all as would be apparent to oneskilled in the art after having the benefit of this description of theinvention. Changes may be made in the elements described herein withoutdeparting from the spirit and scope of the invention as described in thefollowing claims.

1. A method of treating a coal formation in situ, comprising: providingheat from one or more heat sources to at least one portion of theformation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; controlling the heatfrom the one or more heat sources such that an average temperaturewithin at least a majority of the selected section of the formation isless than about 375° C.; and producing a mixture from the formation. 2.The method of claim 1, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some coal within the selectedsection of the formation.
 3. The method of claim 1, wherein controllingformation conditions comprises maintaining a temperature within theselected section within a pyrolysis temperature range.
 4. The method ofclaim 1, wherein the one or more heat sources comprise electricalheaters.
 5. The method of claim 1, wherein the one or more heat sourcescomprise surface burners.
 6. The method of claim 1, wherein the one ormore heat sources comprise flameless distributed combustors.
 7. Themethod of claim 1, wherein the one or more heat sources comprise naturaldistributed combustors.
 8. The method of claim 1, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 9. The method of claim 1, furthercomprising controlling a pressure within at least a majority of theselected section of the formation with a valve coupled to at least oneof the one or more heat sources.
 10. The method of claim 1, furthercomprising controlling a pressure within at least a majority of theselected section of the formation with a valve coupled to a productionwell located in the formation.
 11. The method of claim 1, furthercomprising controlling the heat such that an average heating rate of theselected section is less than about 1° C. per day during pyrolysis. 12.The method of claim 1, wherein providing heat from the one or more heatsources to at least the portion of formation comprises: heating aselected volume (V) of the coal formation from the one or more heatsources, wherein the formation has an average heat capacity(C_(v)), andwherein the heating pyrolyzes at least some coal within the selectedvolume of the formation; and wherein heating energy/day provided to thevolume is equal to or less than Pwr, wherein Pwr is calculated by theequation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, his an average heating rate of the formation, ρ_(B) is formation bulkdensity, and wherein the heating rate is less than about 10° C./day. 13.The method of claim 1, wherein allowing the heat to transfer from theone or more heat sources to the selected section comprises transferringheat substantially by conduction.
 14. The method of claim 1, whereinproviding heat from the one or more heat sources comprises heating theselected section such that a thermal conductivity of at least a portionof the selected section is greater than about 0.5 W/(m° C.).
 15. Themethod of claim 1, wherein the produced mixture comprises condensablehydrocarbons having an API gravity of at least about 25°.
 16. The methodof claim 1, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 17. The method of claim 1,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 18. The method ofclaim 1, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe non-condensable hydrocarbons are olefins.
 19. The method of claim 1,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is nitrogen.
 20. The method ofclaim 1, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 21. Themethod of claim 1, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 22. The methodof claim 1, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 23. Themethod of claim 1, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 24. The method of claim1, wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 25. The methodof claim 1, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 26. The method of claim 1,wherein the produced mixture comprises condensable hydrocarbons, andwherein about 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 27. The method of claim 1, wherein theproduced mixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 28. The method of claim 1, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 29. The method of claim 1,wherein the produced mixture comprises ammonia, and wherein the ammoniais used to produce fertilizer.
 30. The method of claim 1, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 31. The method of claim 1, furthercomprising controlling formation conditions such that the producedmixture comprises a partial pressure of H₂ within the mixture greaterthan about 0.5 bar.
 32. The method of claim 31, wherein the partialpressure of H₂ is measured when the mixture is at a production well. 33.The method of claim 1, wherein controlling formation conditionscomprises recirculating a portion of hydrogen from the mixture into theformation.
 34. The method of claim 1, further comprising altering apressure within the formation to inhibit production of hydrocarbons fromthe formation having carbon numbers greater than about
 25. 35. Themethod of claim 1, further comprising: providing hydrogen (H₂) to theheated section to hydrogenate hydrocarbons within the section; andheating a portion of the section with heat from hydrogenation.
 36. Themethod of claim 1, wherein the produced mixture comprises hydrogen andcondensable hydrocarbons, the method further comprising hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 37. The method of claim 1, wherein allowingthe heat to transfer comprises increasing a permeability of a majorityof the selected section to greater than about 100 millidarcy.
 38. Themethod of claim 1, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 39. The method of claim 1, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 40. The methodof claim 1, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 41. The methodof claim 1, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern. 42.The method of claim 1, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 43. The methodof claim 1, further comprising separating the produced mixture into agas stream and a liquid stream.
 44. The method of claim 1, furthercomprising separating the produced mixture into a gas stream and aliquid stream and separating the liquid stream into an aqueous streamand a non-aqueous stream.
 45. The method of claim 1, wherein theproduced mixture comprises H₂S, the method further comprising separatinga portion of the H₂S from non-condensable hydrocarbons.
 46. The methodof claim 1, wherein the produced mixture comprises CO₂, the methodfurther comprising separating a portion of the CO₂ from non-condensablehydrocarbons.
 47. The method of claim 1, wherein the mixture is producedfrom a production well, wherein the heating is controlled such that themixture can be produced from the formation as a vapor.
 48. The method ofclaim 1, wherein the mixture is produced from a production well, themethod further comprising heating a wellbore of the production well toinhibit condensation of the mixture within the wellbore.
 49. The methodof claim 1, wherein the mixture is produced from a production well,wherein a wellbore of the production well comprises a heater elementconfigured to heat the formation adjacent to the wellbore, and furthercomprising heating the formation with the heater element to produce themixture, wherein the mixture comprises a large non-condensablehydrocarbon gas component and H₂.
 50. The method of claim 1, wherein theminimum pyrolysis temperature is about 270° C.
 51. The method of claim1, further comprising maintaining the pressure within the formationabove about 2.0 bar absolute to inhibit production of fluids havingcarbon numbers above
 25. 52. The method of claim 1, further comprisingcontrolling pressure within the formation in a range from aboutatmospheric pressure to about 100 bar, as measured at a wellhead of aproduction well, to control an amount of condensable hydrocarbons withinthe produced mixture, wherein the pressure is reduced to increaseproduction of condensable hydrocarbons, and wherein the pressure isincreased to increase production of non-condensable hydrocarbons. 53.The method of claim 1, further comprising controlling pressure withinthe formation in a range from about atmospheric pressure to about 100bar, as measured at a wellhead of a production well, to control an APIgravity of condensable hydrocarbons within the produced mixture, whereinthe pressure is reduced to decrease the API gravity, and wherein thepressure is increased to reduce the API gravity.
 54. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from at least the portion to a selected section ofthe formation substantially by conduction of heat; pyrolyzing at leastsome hydrocarbons within the selected section of the formation; andproducing a mixture from the formation.
 55. The method of claim 54,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 56. The method of claim 54, wherein the one or more heatsources comprise electrical heaters.
 57. The method of claim 54, whereinthe one or more heat sources comprise surface burners.
 58. The method ofclaim 54, wherein the one or more heat sources comprise flamelessdistributed combustors.
 59. The method of claim 54, wherein the one ormore heat sources comprise natural distributed combustors.
 60. Themethod of claim 54, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.61. The method of claim 54, further comprising controlling the heat suchthat an average heating rate of the selected section is less than about1.0° C. per day during pyrolysis.
 62. The method of claim 54, whereinproviding heat from the one or more heat sources to at least the portionof formation comprises: heating a selected volume (V) of the coalformation from the one or more heat sources, wherein the formation hasan average heat capacity (C_(v)), and wherein the heating pyrolyzes atleast some hydrocarbons within the selected volume of the formation; andwherein heating energy/day provided to the volume is equal to or lessthan Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 63. The methodof claim 54, wherein providing heat from the one or more heat sourcescomprises heating the selected section such that a thermal conductivityof at least a portion of the selected section is greater than about 0.5W/(m° C.).
 64. The method of claim 54, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 65. The method of claim 54, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins.
 66. Themethod of claim 54, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 67. The method of claim 54, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 68. The method of claim 54, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 69. The method of claim 54, whereinthe produced mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 70. The method of claim 54, whereinthe produced mixture comprises condensable hydrocarbons, wherein about5% by weight to about 30% by weight of the condensable hydrocarbonscomprise oxygen containing compounds, and wherein the oxygen containingcompounds comprise phenols.
 71. The method of claim 54, wherein theproduced mixture comprises condensable hydrocarbons, and wherein greaterthan about 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 72. The method of claim 54, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 73. The method of claim 54, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 74. The method of claim 54, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.75. The method of claim 54, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 76. Themethod of claim 54, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 77. The method of claim 54, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 78. The method of claim 54, further comprising controlling apressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 79. The method of claim 54, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 80. The method of claim 79, wherein the partialpressure of H₂ is measured when the mixture is at a production well. 81.The method of claim 54, further comprising altering a pressure withinthe formation to inhibit production of hydrocarbons from the formationhaving carbon numbers greater than about
 25. 82. The method of claim 54,wherein controlling formation conditions comprises recirculating aportion of hydrogen from the mixture into the formation.
 83. The methodof claim 54, further comprising: providing hydrogen (H₂) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 84. The method ofclaim 54, wherein the produced mixture comprises hydrogen andcondensable hydrocarbons, the method further comprising hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 85. The method of claim 54, wherein allowingthe heat to transfer comprises increasing a permeability of a majorityof the selected section to greater than about 100 millidarcy.
 86. Themethod of claim 54, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 87. The method of claim 54, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 88. The methodof claim 54, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 89. The methodof claim 54, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern. 90.The method of claim 54, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 91. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; and heating the selected section such that athermal conductivity of at least a portion of the selected section isgreater than about 0.5 W/(m° C.).
 92. The method of claim 91, whereinthe one or more heat sources comprise at least two heat sources, andwherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 93. The method of claim 91, wherein controlling formationconditions comprises maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 94. The method of claim91, wherein the one or more heat sources comprise electrical heaters.95. The method of claim 91, wherein the one or more heat sourcescomprise surface burners.
 96. The method of claim 91, wherein the one ormore heat sources comprise flameless distributed combustors.
 97. Themethod of claim 91, wherein the one or more heat sources comprisenatural distributed combustors.
 98. The method of claim 91, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 99. The method of claim 91,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 100. The method of claim 91, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 101. The method of claim 91, wherein allowing theheat to transfer comprises transferring heat substantially byconduction.
 102. The method of claim 91, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 103. The method of claim 91, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 104.The method of claim 91, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 105. The method of claim 91, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 106. The method of claim 91, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 107. The method of claim 91, whereinthe produced mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 108. The method of claim 91, whereinthe produced mixture comprises condensable hydrocarbons, wherein about5% by weight to about 30% by weight of the condensable hydrocarbonscomprise oxygen containing compounds, and wherein the oxygen containingcompounds comprise phenols.
 109. The method of claim 91, wherein theproduced mixture comprises condensable hydrocarbons, and wherein greaterthan about 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 110. The method of claim 91, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 111. The method of claim 91, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 112. The method of claim 91, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.113. The method of claim 91, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 114. Themethod of claim 91, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 115. The method of claim 91, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 116. The method of claim 91, further comprising controllinga pressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 117. The method of claim 91, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 118. The method of claim 117, wherein the partialpressure of H₂ is measured when the mixture is at a production well.119. The method of claim 91, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 120. The methodof claim 91, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.121. The method of claim 91, further comprising: providing hydrogen (H₂)to the heated section to hydrogenate hydrocarbons within the section;and heating a portion of the section with heat from hydrogenation. 122.The method of claim 91, wherein the produced mixture comprises hydrogenand condensable hydrocarbons, the method further comprisinghydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 123. The method of claim 91,wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 124. The method of claim 91, wherein allowing the heatto transfer comprises substantially uniformly increasing a permeabilityof a majority of the selected section.
 125. The method of claim 91,further comprising controlling the heat to yield greater than about 60%by weight of condensable hydrocarbons, as measured by Fischer Assay.126. The method of claim 91, wherein producing the mixture comprisesproducing the mixture in a production well, and wherein at least about 7heat sources are disposed in the formation for each production well.127. The method of claim 91, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, and wherein the unit of heat sourcescomprises a triangular pattern.
 128. The method of claim 91, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, wherein the unit ofheat sources comprises a triangular pattern, and wherein a plurality ofthe units are repeated over an area of the formation to form arepetitive pattern of units.
 129. A method of treating a coal formationin situ, comprising: providing heat from one or more heat sources to atleast a portion of the formation; allowing the heat to transfer from theone or more heat sources to a selected section of the formation;controlling the heat from the one or more heat sources such that anaverage temperature within at least a majority of the selected sectionof the formation is less than about 370° C. such that production of asubstantial amount of hydrocarbons having carbon numbers greater than 25is inhibited; controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast 2.0 bar; and producing a mixture from the formation, wherein about0.1% by weight of the produced mixture to about 15% by weight of theproduced mixture are olefins, and wherein an average carbon number ofthe produced mixture ranges from 1-25.
 130. The method of claim 129,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 131. The method of claim 129, wherein controlling formationconditions comprises maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 132. The method of claim129, wherein the one or more heat sources comprise electrical heaters.133. The method of claim 129, wherein the one or more heat sourcescomprise surface burners.
 134. The method of claim 129, wherein the oneor more heat sources comprise flameless distributed combustors.
 135. Themethod of claim 129, wherein the one or more heat sources comprisenatural distributed combustors.
 136. The method of claim 129, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 137. The method of claim 129,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 138. The method of claim 129, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 139. The method of claim 129, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 140. The method of claim 129, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 141. The method of claim129, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 142. The method of claim 129,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 143. The method ofclaim 129, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 144.The method of claim 129, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 145. The method of claim 129, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 146. The method of claim 129, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 147. The method of claim 129, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 148. The method of claim 129, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 149. The method of claim 129, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 150. The method of claim 129, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.151. The method of claim 129, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 152. Themethod of claim 129, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 153. The method of claim 129, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 154. The method of claim 129, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 155. The method of claim 154, wherein the partialpressure of H₂ is measured when the mixture is at a production well.156. The method of claim 129, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 157. The methodof claim 129, further comprising: providing hydrogen (H₂) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 158. The method ofclaim 129, wherein the produced mixture comprises hydrogen andcondensable hydrocarbons, the method further comprising hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 159. The method of claim 129, wherein allowingthe heat to transfer comprises increasing a permeability of a majorityof the selected section to greater than about 100 millidarcy.
 160. Themethod of claim 129, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 161. The method of claim 129, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 162. The methodof claim 129, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 163. The methodof claim 129, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.164. The method of claim 129, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.165. The method of claim 129, further comprising separating the producedmixture into a gas stream and a liquid stream.
 166. The method of claim129, further comprising separating the produced mixture into a gasstream and a liquid stream and separating the liquid stream into anaqueous stream and a non-aqueous stream.
 167. The method of claim 129,wherein the produced mixture comprises H₂S, the method furthercomprising separating a portion of the H₂S from non-condensablehydrocarbons.
 168. The method of claim 129, wherein the produced mixturecomprises CO₂, the method further comprising separating a portion of theCO₂ from non-condensable hydrocarbons.
 169. The method of claim 129,wherein the mixture is produced from a production well, wherein theheating is controlled such that the mixture can be produced from theformation as a vapor.
 170. The method of claim 129, wherein the mixtureis produced from a production well, the method further comprisingheating a wellbore of the production well to inhibit condensation of themixture within the wellbore.
 171. The method of claim 129, wherein themixture is produced from a production well, wherein a wellbore of theproduction well comprises a heater element configured to heat theformation adjacent to the wellbore, and further comprising heating theformation with the heater element to produce the mixture, wherein theproduced mixture comprise a large non-condensable hydrocarbon gascomponent and H₂.
 172. The method of claim 129, wherein the minimumpyrolysis temperature is about 270° C.
 173. The method of claim 129,further comprising maintaining the pressure within the formation aboveabout 2.0 bar absolute to inhibit production of fluids having carbonnumbers above
 25. 174. The method of claim 129, further comprisingcontrolling pressure within the formation in a range from aboutatmospheric pressure to about 100 bar absolute, as measured at awellhead of a production well, to control an amount of condensablefluids within the produced mixture, wherein the pressure is reduced toincrease production of condensable fluids, and wherein the pressure isincreased to increase production of non-condensable fluids.
 175. Themethod of claim 129, further comprising controlling pressure within theformation in a range from about atmospheric pressure to about 100 barabsolute, as measured at a wellhead of a production well, to control anAPI gravity of condensable fluids within the produced mixture, whereinthe pressure is reduced to decrease the API gravity, and wherein thepressure is increased to reduce the API gravity.
 176. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; controlling a pressure within at least amajority of the selected section of the formation, wherein thecontrolled pressure is at least about 2.0 bar absolute; and producing amixture from the formation.
 177. The method of claim 176, whereincontrolling the pressure comprises controlling the pressure with a valvecoupled to at least one of the one or more heat sources.
 178. The methodof claim 176, wherein controlling the pressure comprises controlling thepressure with a valve coupled to a production well located in theformation.
 179. The method of claim 176, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation.
 180. Themethod of claim 176, wherein controlling formation conditions comprisesmaintaining a temperature within the selected section within a pyrolysistemperature range.
 181. The method of claim 176, wherein the one or moreheat sources comprise electrical heaters.
 182. The method of claim 176,wherein the one or more heat sources comprise surface burners.
 183. Themethod of claim 176, wherein the one or more heat sources compriseflameless distributed combustors.
 184. The method of claim 176, whereinthe one or more heat sources comprise natural distributed combustors.185. The method of claim 176, further comprising controlling atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.186. The method of claim 176, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 187. The method of claim 176,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 188. The methodof claim 176, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 189. The method of claim176, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 190. The method of claim 176, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 191. The method of claim 176, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 192.The method of claim 176, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 193. The method of claim 176, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 194. The method of claim 176, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 195. The method of claim 176,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 196. The method ofclaim 176, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 197. Themethod of claim 176, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 198. The method ofclaim 176, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 199. The method of claim 176, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 200. The methodof claim 176, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 201. The method of claim176, wherein the produced mixture comprises a non-condensable component,wherein the non-condensable component comprises hydrogen, wherein thehydrogen is greater than about 10% by volume of the non-condensablecomponent, and wherein the hydrogen is less than about 80% by volume ofthe non-condensable component.
 202. The method of claim 176, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 203. The method of claim176, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 204. The method of claim 176,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 205. The method ofclaim 204, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 206. The method of claim 176, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 207. The method of claim 176, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 208. The method of claim 176, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 209. The method of claim 176, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 210. The method of claim 176, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 211. The methodof claim 176, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 212. The method of claim 176, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 213. The methodof claim 176, wherein producing the mixture from the formation comprisesproducing the mixture in a production well, and wherein at least about 7heat sources are disposed in the formation for each production well.214. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and controlling apressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute; controlling the heat from the one or more heat sources suchthat an average temperature within at least a majority of the selectedsection of the formation is less than about 375° C.; and producing amixture from the formation.
 215. The method of claim 214, wherein theone or more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.216. The method of claim 214, wherein controlling formation conditionscomprises maintaining a temperature within the selected section within apyrolysis temperature range.
 217. The method of claim 214, wherein theone or more heat sources comprise electrical heaters.
 218. The method ofclaim 214, wherein the one or more heat sources comprise surfaceburners.
 219. The method of claim 214, wherein the one or more heatsources comprise flameless distributed combustors.
 220. The method ofclaim 214, wherein the one or more heat sources comprise naturaldistributed combustors.
 221. The method of claim 214, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 222. The method of claim 214,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 223. The method of claim 214, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 224. The method of claim 214, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 225. The method of claim 214, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 226. The method of claim214, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 227. The method of claim214, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 228. The method of claim 214,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 229. The method of claim 214,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 230. The method ofclaim 214, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 231.The method of claim 214, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 232. The method of claim 214, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 233. The method of claim 214, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 234. The method of claim 214, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 235. The method of claim 214, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 236. The method of claim 214, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 237. The method of claim 214, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.238. The method of claim 214, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 239. Themethod of claim 214, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 240. The method of claim 214, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 241. The method of claim 214, wherein controlling the heatfurther comprises controlling the heat such that coke production isinhibited.
 242. The method of claim 214, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 243. The method of claim 242, wherein the partialpressure of H₂ is measured when the mixture is at a production well.244. The method of claim 214, further comprising altering the pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 245. The methodof claim 214, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.246. The method of claim 214, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 247. The method of claim 214, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 248. Themethod of claim 214, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 249. The method of claim 214, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 250.The method of claim 214, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 251. The method of claim 214, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 252. The method of claim 214,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 253.The method of claim 214, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 254. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; producing a mixture from the formation,wherein at least a portion of the mixture is produced during thepyrolysis and the mixture moves through the formation in a vapor phase;and maintaining a pressure within at least a majority of the selectedsection above about 2.0 bar absolute.
 255. The method of claim 254,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 256. The method of claim 254, wherein controlling formationconditions comprises maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 257. The method of claim254, wherein the one or more heat sources comprise electrical heaters.258. The method of claim 254, wherein the one or more heat sourcescomprise surface burners.
 259. The method of claim 254, wherein the oneor more heat sources comprise flameless distributed combustors.
 260. Themethod of claim 254, wherein the one or more heat sources comprisenatural distributed combustors.
 261. The method of claim 254, furthercomprising controlling the pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 262. The method of claim 254,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 263. The method of claim 254, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 264. The method of claim 254, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 265. The method of claim 254, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 266. The method of claim254, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 267. The method of claim254, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 268. The method of claim 254,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 269. The method of claim 254,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 270. The method ofclaim 254, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 271.The method of claim 254, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 272. The method of claim 254, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 273. The method of claim 254, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 274. The method of claim 254, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 275. The method of claim 254, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 276. The method of claim 254, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 277. The method of claim 254, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.278. The method of claim 254, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 279. Themethod of claim 254, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 280. The method of claim 254, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 281. The method of claim 254, wherein the pressure ismeasured at a wellhead of a production well.
 282. The method of claim254, wherein the pressure is measured at a location within a wellbore ofthe production well.
 283. The method of claim 254, wherein the pressureis maintained below about 100 bar absolute.
 284. The method of claim254, further comprising controlling formation conditions to produce amixture of condensable hydrocarbons and H₂, wherein a partial pressureof H₂ within the mixture is greater than about 0.5 bar.
 285. The methodof claim 284, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 286. The method of claim 254, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 287. The method of claim 254, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 288. The method of claim 254, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 289. The method of claim 254, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 290. The method of claim 254, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 291. The methodof claim 254, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 292. The method of claim 254, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 293. The methodof claim 254, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 294. The methodof claim 254, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.295. The method of claim 254, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit-of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.296. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; maintaining a pressurewithin at least a majority of the selected section of the formationabove 2.0 bar absolute; and producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons havingan API gravity higher than an API gravity of condensable hydrocarbons ina mixture producible from the formation at the same temperature and atatmospheric pressure.
 297. The method of claim 296, wherein the one ormore heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.298. The method of claim 296, wherein controlling formation conditionscomprises maintaining a temperature within the selected section within apyrolysis temperature range.
 299. The method of claim 296, wherein theone or more heat sources comprise electrical heaters.
 300. The method ofclaim 296, wherein the one or more heat sources comprise surfaceburners.
 301. The method of claim 296, wherein the one or more heatsources comprise flameless distributed combustors.
 302. The method ofclaim 296, wherein the one or more heat sources comprise naturaldistributed combustors.
 303. The method of claim 296, further comprisingcontrolling the pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 304. The method of claim 296,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 305. The method of claim 296, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (B) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 306. The method of claim 296, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 307. The method of claim 296, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 308. The method of claim296, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 309. The method of claim296, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 310. The method of claim 296,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 311. The method of claim 296,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 312. The method ofclaim 296, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 313.The method of claim 296, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 314. The method of claim 296, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 315. The method of claim 296, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 316. The method of claim 296, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 317. The method of claim 296, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 318. The method of claim 296, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 319. The method of claim 296, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.320. The method of claim 296, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 321. Themethod of claim 296, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 322. The method of claim 296, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 323. The method of claim 296, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 324. The method of claim 296, wherein the partialpressure of H₂ is measured when the mixture is at a production well.325. The method of claim 296, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 326. The methodof claim 296, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.327. The method of claim 296, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 328. The method of claim 296, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 329. Themethod of claim 296, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 330. The method of claim 296, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 331.The method of claim 296, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 332. The method of claim 296, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 333. The method of claim 296,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 334.The method of claim 296, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 335. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; maintaining a pressure within at least amajority of the selected section of the formation to above 2.0 barabsolute; and producing a fluid from the formation, wherein condensablehydrocarbons within the fluid comprise an atomic hydrogen to atomiccarbon ratio of greater than about 1.75.
 336. The method of claim 335,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 337. The method of claim 335, wherein controlling formationconditions comprises maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 338. The method of claim335, wherein the one or more heat sources comprise electrical heaters.339. The method of claim 335, wherein the one or more heat sourcescomprise surface burners.
 340. The method of claim 335, wherein the oneor more heat sources comprise flameless distributed combustors.
 341. Themethod of claim 335, wherein the one or more heat sources comprisenatural distributed combustors.
 342. The method of claim 335, furthercomprising controlling the pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 343. The method of claim 335,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 344. The method of claim 335, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 345. The method of claim 335, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 346. The method of claim 335, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 347. The method of claim335, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 348. The method of claim335, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 349. The method of claim 335,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 350. The method of claim 335,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 351. The method ofclaim 335, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 352.The method of claim 335, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 353. The method of claim 335, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 354. The method of claim 335, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 355. The method of claim 335, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 356. The method of claim 335, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 357. The method of claim 335, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 358. The method of claim 335, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.359. The method of claim 335, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 360. Themethod of claim 335, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 361. The method of claim 335, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 362. The method of claim 335, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 363. The method of claim 335, wherein the partialpressure of H₂ is measured when the mixture is at a production well.364. The method of claim 335, further comprising altering the pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 365. The methodof claim 335, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.366. The method of claim 335, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 367. The method of claim 335, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 368. Themethod of claim 335, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 369. The method of claim 335, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 370.The method of claim 335, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 371. The method of claim 335, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 372. The method of claim 335,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 373.The method of claim 335, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 374. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; maintaining a pressure within at least amajority of the selected section of the formation to above 2.0 barabsolute; and producing a mixture from the formation, wherein theproduced mixture comprises a higher amount of non-condensable componentsas compared to non-condensable components producible from the formationunder the same temperature conditions and at atmospheric pressure. 375.The method of claim 374, wherein the one or more heat sources compriseat least two heat sources, and wherein superposition of heat from atleast the two heat sources pyrolyzes at least some hydrocarbons withinthe selected section of the formation.
 376. The method of claim 374,wherein controlling formation conditions comprises maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 377. The method of claim 374, wherein the one or more heatsources comprise electrical heaters.
 378. The method of claim 374,wherein the one or more heat sources comprise surface burners.
 379. Themethod of claim 374, wherein the one or more heat sources compriseflameless distributed combustors.
 380. The method of claim 374, whereinthe one or more heat sources comprise natural distributed combustors.381. The method of claim 374, further comprising controlling thepressure and a temperature within at least a majority of the selectedsection of the formation, wherein the pressure is controlled as afunction of temperature, or the temperature is controlled as a functionof pressure.
 382. The method of claim 374, further comprisingcontrolling the heat such that an average heating rate of the selectedsection is less than about 1° C. per day during pyrolysis.
 383. Themethod of claim 374, wherein providing heat from the one or more heatsources to at least the portion of formation comprises: heating aselected volume (V) of the coal formation from the one or more heatsources, wherein the formation has an average heat capacity (C_(v)), andwherein the heating pyrolyzes at least some hydrocarbons within theselected volume of the formation; and wherein heating energy/dayprovided to the volume is equal to or less than Pwr, wherein Pwr iscalculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is theheating energy/day, h is an average heating rate of the formation, ρ_(B)is formation bulk density, and wherein the heating rate is less thanabout 10° C./day.
 384. The method of claim 374, wherein allowing theheat to transfer comprises transferring heat substantially byconduction.
 385. The method of claim 374, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 386. The method of claim374, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 387. The method of claim374, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 388. The method of claim 374,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 389. The method of claim 374,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 390. The method ofclaim 374, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 391.The method of claim 374, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 392. The method of claim 374, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 393. The method of claim 374, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 394. The method of claim 374, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 395. The method of claim 374, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 396. The method of claim 374, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 397. The method of claim 374, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.398. The method of claim 374, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 399. Themethod of claim 374, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 400. The method of claim 374, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 401. The method of claim 374, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 402. The method of claim 374, wherein the partialpressure of H₂ is measured when the mixture is at a production well.403. The method of claim 374, further comprising altering the pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 404. The methodof claim 374, further comprising: providing hydrogen (H₂) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 405. The method ofclaim 374, wherein the produced mixture comprises hydrogen andcondensable hydrocarbons, the method further comprising hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 406. The method of claim 374, wherein allowingthe heat to transfer comprises increasing a permeability of a majorityof the selected section to greater than about 100 millidarcy.
 407. Themethod of claim 374, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 408. The method of claim 374, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 409. The methodof claim 374, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 410. The methodof claim 374, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.411. The method of claim 374, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.412. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation such that superimposedheat from the one or more heat sources pyrolyzes at least about 20% byweight of hydrocarbons within the selected section of the formation; andproducing a mixture from the formation.
 413. The method of claim 412,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 414. The method of claim 412, wherein controlling formationconditions comprises maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 415. The method of claim412, wherein the one or more heat sources comprise electrical heaters.416. The method of claim 412, wherein the one or more heat sourcescomprise surface burners.
 417. The method of claim 412, wherein the oneor more heat sources comprise flameless distributed combustors.
 418. Themethod of claim 412, wherein the one or more heat sources comprisenatural distributed combustors.
 419. The method of claim 412, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 420. The method of claim 412,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 421. The method of claim 412, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 422. The method of claim 412, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 423. The method of claim 412, wherein providing heat fromthe one or more heat sources comprises heating the selected formationsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 424. The method of claim412, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 425. The method of claim412, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 426. The method of claim 412,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 427. The method of claim 412,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 428. The method ofclaim 412, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 429.The method of claim 412, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 430. The method of claim 412, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 431. The method of claim 412, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 432. The method of claim 412, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 433. The method of claim 412, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 434. The method of claim 412, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 435. The method of claim 412, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.436. The method of claim 412, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 437. Themethod of claim 412, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 438. The method of claim 412, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 439. The method of claim 412, further comprising controllinga pressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 440. The method of claim 412, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 441. The method of claim 412, wherein the partialpressure of H₂ is measured when the mixture is at a production well.442. The method of claim 412, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 443. The methodof claim 412, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.444. The method of claim 412, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 445. The method of claim 412, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 446. Themethod of claim 412, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 447. The method of claim 412, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 448.The method of claim 412, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 449. The method of claim 412, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 450. The method of claim 412,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 451.The method of claim 412, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 452. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation such that superimposed heat from the one ormore heat sources pyrolyzes at least about 20% of hydrocarbons withinthe selected section of the formation; and producing a mixture from theformation, wherein the mixture comprises a condensable component havingan API gravity of at least about 25°.
 453. The method of claim 452,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 454. The method of claim 452, wherein controlling formationconditions comprises maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 455. The method of claim452, wherein the one or more heat sources comprise electrical heaters.456. The method of claim 452, wherein the one or more heat sourcescomprise surface burners.
 457. The method of claim 452, wherein the oneor more heat sources comprise flameless distributed combustors.
 458. Themethod of claim 452, wherein the one or more heat sources comprisenatural distributed combustors.
 459. The method of claim 452, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 460. The method of claim 452,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 461. The method of claim 452, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 462. The method of claim 452, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 463. The method of claim 452, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 464. The method of claim452, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 465. The method of claim 452,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 466. The method of claim 452,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 467. The method ofclaim 452, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 468.The method of claim 452, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 469. The method of claim 452, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 470. The method of claim 452, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 471. The method of claim 452, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 472. The method of claim 452, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 473. The method of claim 452, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 474. The method of claim 452, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.475. The method of claim 452, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 476. Themethod of claim 452, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 477. The method of claim 452, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 478. The method of claim 452, further comprising controllinga pressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 479. The method of claim 452, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 480. The method of claim 452, wherein the partialpressure of H₂ is measured when the mixture is at a production well.481. The method of claim 452, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 482. The methodof claim 452, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.483. The method of claim 452, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 484. The method of claim 452, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 485. Themethod of claim 452, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 486. The method of claim 452, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 487.The method of claim 452, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 488. The method of claim 452, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 489. The method of claim 452,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 490.The method of claim 452, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 491. A method oftreating a layer of a coal formation in situ, comprising: providing heatfrom one or more heat sources to at least a portion of the layer,wherein the one or more heat sources are positioned proximate an edge ofthe layer; allowing the heat to transfer from the one or more heatsources to a selected section of the layer such that superimposed heatfrom the one or more heat sources pyrolyzes at least some hydrocarbonswithin the selected section of the formation; and producing a mixturefrom the formation.
 492. The method of claim 491, wherein the one ormore heat sources are laterally spaced from a center of the layer. 493.The method of claim 491, wherein the one or more heat sources arepositioned in a staggered line.
 494. The method of claim 491, whereinthe one or more heat sources positioned proximate the edge of the layercan increase an amount of hydrocarbons produced per unit of energy inputto the one or more heat sources.
 495. The method of claim 491, whereinthe one or more heat sources positioned proximate the edge of the layercan increase the volume of formation undergoing pyrolysis per unit ofenergy input to the one or more heat sources.
 496. The method of claim491, wherein the one or more heat sources comprise electrical heaters.497. The method of claim 491, wherein the one or more heat sourcescomprise surface burners.
 498. The method of claim 491, wherein the oneor more heat sources comprise flameless distributed combustors.
 499. Themethod of claim 491, wherein the one or more heat sources comprisenatural distributed combustors.
 500. The method of claim 491, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 501. The method of claim 491,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1.0° C. per day duringpyrolysis.
 502. The method of claim 491, wherein providing heat from theone or more heat sources to at least the portion of the layer comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 503. The method of claim 491, wherein providingheat from the one or more heat sources comprises heating the selectedsection such that a thermal conductivity of at least a portion of theselected section is greater than about 0.5 W/(m° C.).
 504. The method ofclaim 491, wherein the produced mixture comprises condensablehydrocarbons having an API gravity of at least about 25°.
 505. Themethod of claim 491, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 506. The method of claim 491,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 507. The method ofclaim 491, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 508.The method of claim 491, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 509. The method of claim 491, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 510. The method of claim 491, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 511. The method of claim 491, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 512. The method of claim 491, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 513. The method of claim 491, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 514. The method of claim 491, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.515. The method of claim 491, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 516. Themethod of claim 491, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 517. The method of claim 491, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 518. The method of claim 491, further comprising controllinga pressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 519. The method of claim 491, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 520. The method of claim 519, wherein the partialpressure of H₂ is measured when the mixture is at a production well.521. The method of claim 491, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 522. The methodof claim 491, further comprising controlling formation conditions,wherein controlling formation conditions comprises recirculating aportion of hydrogen from the mixture into the formation.
 523. The methodof claim 491, further comprising: providing hydrogen (H2) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 524. The method ofclaim 491, wherein the produced mixture comprises hydrogen andcondensable hydrocarbons, the method further comprising hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 525. The method of claim 491, wherein allowingthe heat to transfer comprises increasing a permeability of a majorityof the selected section to greater than about 100 millidarcy.
 526. Themethod of claim 491, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 527. The method of claim 491, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 528. The methodof claim 491, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 529. The methodof claim 491, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.530. The method of claim 491, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.531. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and controlling apressure and a temperature within at least a majority of the selectedsection of the formation, wherein the pressure is controlled as afunction of temperature, or the temperature is controlled as a functionof pressure; and producing a mixture from the formation.
 532. The methodof claim 531, wherein the one or more heat sources comprise at least twoheat sources, and wherein superposition of heat from at least the twoheat sources pyrolyzes at least some hydrocarbons within the selectedsection of the formation.
 533. The method of claim 531, whereincontrolling formation conditions comprises maintaining a temperaturewithin the selected section within a pyrolysis temperature range. 534.The method of claim 531, wherein the one or more heat sources compriseelectrical heaters.
 535. The method of claim 531, wherein the one ormore heat sources comprise surface burners.
 536. The method of claim531, wherein the one or more heat sources comprise flameless distributedcombustors.
 537. The method of claim 531, wherein the one or more heatsources comprise natural distributed combustors.
 538. The method ofclaim 531, further comprising controlling the heat such that an averageheating rate of the selected section is less than about 1° C. per dayduring pyrolysis.
 539. The method of claim 531, wherein providing heatfrom the one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 540. The method of claim 531, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 541. The method of claim 531, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 542. The method of claim531, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 543. The method of claim531, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 544. The method of claim 531,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 545. The method of claim 531,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons range s from about 0.001 to about 0.15.
 546. The method ofclaim 531, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 547.The method of claim 531, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 548. The method of claim 531, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 549. The method of claim 531, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 550. The method of claim 531, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 551. The method of claim 531, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 552. The method of claim 531, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 553. The method of claim 531, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.554. The method of claim 531, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 555. Themethod of claim 531, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 556. The method of claim 531, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 557. The method of claim 531, wherein the controlledpressure is at least about 2.0 bar absolute.
 558. The method of claim531, further comprising controlling formation conditions to produce amixture of condensable hydrocarbons and H₂, wherein a partial pressureof H₂ within the mixture is greater than about 0.5 bar.
 559. The methodof claim 531, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 560. The method of claim 531, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 561. The method of claim 531, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 562. The method of claim 531, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 563. The method of claim 531, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 564. The method of claim 531, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 565. The methodof claim 531, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 566. The method of claim 531, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 567. The methodof claim 531, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 568. The methodof claim 531, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.569. The method of claim 531, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.570. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation to raise an averagetemperature within the selected section to, or above, a temperature thatwill pyrolyze hydrocarbons within the selected section; producing amixture from the formation; and controlling API gravity of the producedmixture to be greater than about 25 degrees API by controlling averagepressure and average temperature in the selected section such that theaverage pressure in the selected section is greater than the pressure(p) set forth in the following equation for an assessed averagetemperature (7) in the selected section: p=e ^([−44000/T+67]) where p ismeasured in psia and T is measured in ° Kelvin.
 571. The method of claim570, wherein the API gravity of the produced mixture is controlled to begreater than about 30 degrees API, and wherein the equation is: p=e^([−31000/T+51]).
 572. The method of claim 570, wherein the API gravityof the produced mixture is controlled to be greater than about 35degrees API, and wherein the equation is: p=e ^([−22000/T+38]).
 573. Themethod of claim 570, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 574. The method of claim 570, whereincontrolling the average temperature comprises maintaining a temperaturein the selected section within a pyrolysis temperature range.
 575. Themethod of claim 570, wherein the one or more heat sources compriseelectrical heaters.
 576. The method of claim 570, wherein the one ormore heat sources comprise surface burners.
 577. The method of claim570, wherein the one or more heat sources comprise flameless distributedcombustors.
 578. The method of claim 570, wherein the one or more heatsources comprise natural distributed combustors.
 579. The method ofclaim 570, further comprising controlling a temperature within at leasta majority of the selected section of the formation, wherein thepressure is controlled as a function of temperature, or the temperatureis controlled as a function of pressure.
 580. The method of claim 570,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 581. The method of claim 570, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 582. The method of claim 570, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 583. The method of claim 570, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 584. The method of claim570, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 585. The method of claim 570,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 586. The method of claim 570,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 587. The method ofclaim 570, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 588.The method of claim 570, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 589. The method of claim 570, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 590. The method of claim 570, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 591. The method of claim 570, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 592. The method of claim 570, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 593. The method of claim 570, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 594. The method of claim 570, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.595. The method of claim 570, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 596. Themethod of claim 570, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 597. The method of claim 570, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 598. The method of claim 570, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 599. The method of claim 570, wherein the partialpressure of H₂ is measured when the mixture is at a production well.600. The method of claim 570, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 601. The methodof claim 570, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.602. The method of claim 570, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 603. The method of claim 570, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 604. Themethod of claim 570, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 605. The method of claim 570, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 606.The method of claim 570, wherein the heat is controlled to yield greaterthan about 60% by weight of condensable hydrocarbons, as measured byFischer Assay.
 607. The method of claim 570, wherein producing themixture comprises producing the mixture in a production well, andwherein at least about 7 heat sources are disposed in the formation foreach production well.
 608. The method of claim 570, further comprisingproviding heat from three or more heat sources to at least a portion ofthe formation, wherein three or more of the heat sources are located inthe formation in a unit of heat sources, and wherein the unit of heatsources comprises a triangular pattern.
 609. The method of claim 570,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, whereinthe unit of heat sources comprises a triangular pattern, and wherein aplurality of the units are repeated over an area of the formation toform a repetitive pattern of units.
 610. A method of treating a coalformation in situ, comprising: providing heat to at least a portion of acoal formation such that a temperature (7) in a substantial part of theheated portion exceeds 270° C. and hydrocarbons are pyrolyzed within theheated portion of the formation; controlling a pressure (p) within atleast a substantial part of the heated portion of the formation; whereinP _(bar) >e ^([(−A/T)+) B−26744]; wherein p is the pressure in barabsolute and T is the temperature in degrees K, and A and B areparameters that are larger than 10 and are selected in relation to thecharacteristics and composition of the coal formation and on therequired olefin content and carbon number of the pyrolyzed hydrocarbonfluids; and producing pyrolyzed hydrocarbon fluids from the heatedportion of the formation.
 611. The method of claim 610, wherein A isgreater than 14000 and B is greater than about 25 and a majority of theproduced pyrolyzed hydrocarbon fluids have an average carbon numberlower than 25 and comprise less than about 10% by weight of olefins.612. The method of claim 610, wherein T is less than about 390° C., p isgreater than about 1.4 bar, A is greater than about 44000, and b isgreater than about 67, and a majority of the produced pyrolyzedhydrocarbon fluids have an average carbon number less than 25 andcomprise less than 10% by weight of olefins.
 613. The method of claim610, wherein T is less than about 390° C., p is greater than about 2bar, A is less than about 57000, and b is less than about 83, and amajority of the produced pyrolyzed hydrocarbon fluids have an averagecarbon number lower than about
 21. 614. The method of claim 610, furthercomprising controlling the heat such that an average heating rate of theheated portion is less than about 3° C. per day during pyrolysis. 615.The method of claim 610, wherein providing heat from the one or moreheat sources to at least the portion of formation comprises: heating aselected volume (V) of the coal formation from the one or more heatsources, wherein the formation has an average heat capacity (C_(v)), andwherein the heating pyrolyzes at least some hydrocarbons within theselected volume of the formation; and wherein heating energy/dayprovided to the volume is equal to or less than Pwr, wherein Pwr iscalculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is theheating energy/day, h is an average heating rate of the formation, ρ_(B)is formation bulk density, and wherein the heating rate is less thanabout 10° C./day.
 616. The method of claim 610, wherein heat istransferred substantially by conduction from one or more heat sourceslocated in one or more heat sources to the heated portion of theformation.
 617. The method of claim 616, wherein the heat sourcescomprise heaters in which hydrocarbons are either injected into aheaters or released by the coal formation adjacent to a heater by anoxidant injected into the heater in or adjacent to which the combustionoccurs and wherein at least part of the produced combustion gases arevented to surface via the heater in which the combustion occurs. 618.The method of claim 617, wherein heat is transferred substantially byconduction from one or more heat sources to the heated portion of theformation such that the thermal conductivity of at least part of theheated portion is substantially uniformly modified to a value greaterthan about 0.6 W/m° C. and the permeability of said part increasessubstantially uniformly to a value greater than 1 Darcy.
 619. The methodof claim 610, further comprising controlling formation conditions toproduce a mixture of hydrocarbon fluids and H₂, wherein a partialpressure of H₂ within the mixture flowing through the formation isgreater than 0.5 Bar.
 620. The method of claim 619, further comprising,hydrogenating a portion of the produced pyrolyzed hydrocarbon fluidswith at least a portion of the produced hydrogen and heating the fluidswith heat from hydrogenation.
 621. The method of claim 610, wherein thecoal formation is a coal seam and at least about 70% of the hydrocarboncontent of the coal, when such hydrocarbon content is measured by aFischer assay, is produced from the heated portion of the formation.622. The method of claim 610, wherein the substantially gaseouspyrolyzed hydrocarbon fluids are produced from a production well, themethod further comprising heating a wellbore of the production well toinhibit condensation of the hydrocarbon fluids within the wellbore. 623.A method of treating a coal formation in situ, comprising: providingheat from one or more heat sources to at least a portion of theformation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation to raise an averagetemperature within the selected section to, or above, a temperature thatwill pyrolyze hydrocarbons within the selected section; producing amixture from the formation; and controlling a weight percentage ofolefins of the produced mixture to be less than about 20% by weight bycontrolling average pressure and average temperature in the selectedsection such that the average pressure in the selected section isgreater than the pressure (p) set forth in the following equation for anassessed average temperature (7) in the selected section: p=e^([−57000/T+83]) where p is measured in psia and T is measured in °Kelvin.
 624. The method of claim 623, wherein the weight percentage ofolefins of the produced mixture is controlled to be less than about 10%by weight, and wherein the equation is: p=e ^([−16000/T+28]).
 625. Themethod of claim 623, wherein the weight percentage of olefins of theproduced mixture is controlled to be less than about 5% by weight, andwherein the equation is: p=e ^([−12000/T+22]).
 626. The method of claim623, wherein the one or more heat sources comprise at least two heatsources, and wherein superposition of heat from at least the two heatsources pyrolyzes at least some hydrocarbons within the selected sectionof the formation.
 627. The method of claim 623, wherein the one or moreheat sources comprise electrical heaters.
 628. The method of claim 623,wherein the one or more heat sources comprise surface burners.
 629. Themethod of claim 623, wherein the one or more heat sources compriseflameless distributed combustors.
 630. The method of claim 623, whereinthe one or more heat sources comprise natural distributed combustors.631. The method of claim 623, further comprising controlling atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.632. The method of claim 631, wherein controlling an average temperaturecomprises maintaining a temperature within the selected section within apyrolysis temperature range.
 633. The method of claim 623, furthercomprising controlling the heat such that an average heating rate of theselected section is less than about 3.0° C. per day during pyrolysis.634. The method of claim 623, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 635. The method of claim 623,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 636. The methodof claim 623, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 637. The method of claim623, wherein providing heat from the one or more heat sources comprisesheating the selected formation such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 638. The method of claim 623, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 639. The method of claim 623, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 640.The method of claim 623, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 641. Themethod of claim 623, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 642. The method of claim 623, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 643. The method of claim 623, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 644. The method of claim 623,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 645. The method ofclaim 623, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 646. Themethod of claim 623, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 647. The method ofclaim 623, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 648. The method of claim 623, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 649. The methodof claim 623, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 650. The method of claim623, wherein the produced mixture comprises a non-condensable component,wherein the non-condensable component comprises hydrogen, wherein thehydrogen is greater than about 10% by volume of the non-condensablecomponent, and wherein the hydrogen is less than about 80% by volume ofthe non-condensable component.
 651. The method of claim 623, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 652. The method of claim623, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 653. The method of claim 623,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 654. The method ofclaim 623, wherein the partial pressure of H₂ is measured when the 30mixture is at a production well.
 655. The method of claim 623, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 656. The method of claim 623, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 657. The method of claim 623, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 658. The method of claim 623, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 659. The method of claim 623, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 660. The methodof claim 623, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 661. The method of claim 623, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 662. The methodof claim 623, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 663. The methodof claim 623, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.664. The method of claim 623, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.665. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation to raise an averagetemperature within the selected section to, or above, a temperature thatwill pyrolyze hydrocarbons within the selected section; producing amixture from the formation; and controlling hydrocarbons having carbonnumbers greater than 25 of the produced mixture to be less than about25% by weight by controlling average pressure and average temperature inthe selected section such that the average pressure in the selectedsection is greater than the pressure (p) set forth in the followingequation for an assessed average temperature (T) in the selectedsection: p=e ^([−14000/T+25]) where p is measured in psia and T ismeasured in ° Kelvin.
 666. The method of claim 665, wherein thehydrocarbons having carbon numbers greater than 25 of the producedmixture is controlled to be less than about 20% by weight, and whereinthe equation is: p=e ^([−16000/T+28]).
 667. The method of claim 665,wherein the hydrocarbons having carbon numbers greater than 25 of theproduced mixture is controlled to be less than about 15% by weight, andwherein the equation is: p=e ^([−18000/T+32]).
 668. The method of claim665, wherein the one or more heat sources comprise at least two heatsources, and wherein superposition of heat from at least the two heatsources pyrolyzes at least some hydrocarbons within the selected sectionof the formation.
 669. The method of claim 665, wherein the one or moreheat sources comprise electrical heaters.
 670. The method of claim 665,wherein the one or more heat sources comprise surface burners.
 671. Themethod of claim 665, wherein the one or more heat sources compriseflameless distributed combustors.
 672. The method of claim 665, whereinthe one or more heat sources comprise natural distributed combustors.673. The method of claim 665, further comprising controlling atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.674. The method of claim 673, wherein controlling the temperaturecomprises maintaining a temperature within the selected section within apyrolysis temperature range.
 675. The method of claim 665, furthercomprising controlling the heat such that an average heating rate of theselected section is less than about 1° C. per day during pyrolysis. 676.The method of claim 665, wherein providing heat from the one or moreheat sources to at least the portion of formation comprises: heating aselected volume (V) of the coal formation from the one or more heatsources, wherein the formation has an average heat capacity (C_(v)), andwherein the heating pyrolyzes at least some hydrocarbons within theselected volume of the formation; and wherein heating energy/dayprovided to the volume is equal to or less than Pwr, wherein Pwr iscalculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is theheating energy/day, h is an average heating rate of the formation, ρ_(B)is formation bulk density, and wherein the heating rate is less thanabout 10° C./day.
 677. The method of claim 665, wherein allowing theheat to transfer comprises transferring heat substantially byconduction.
 678. The method of claim 665, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 679. The method of claim665, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 680. The method of claim665, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 681. The method of claim 665,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 682. The method ofclaim 665, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 683.The method of claim 665, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 684. The method of claim 665, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 685. The method of claim 665, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 686. The method of claim 665, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 687. The method of claim 665, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 688. The method of claim 665, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 689. The method of claim 665, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.690. The method of claim 665, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 691. Themethod of claim 665, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 692. The method of claim 665, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 693. The method of claim 665, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 694. The method of claim 665, wherein the partialpressure of H₂ is measured when the mixture is at a production well.695. The method of claim 665, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 696. The methodof claim 665, further comprising: providing hydrogen (H₂) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 697. The method ofclaim 665, wherein the produced mixture comprises hydrogen andcondensable hydrocarbons, the method further comprising hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 698. The method of claim 665, wherein allowingthe heat to transfer comprises increasing a permeability of a majorityof the selected section to greater than about 100 millidarcy.
 699. Themethod of claim 665, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 700. The method of claim 665, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 701. The methodof claim 665, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 702. The methodof claim 665, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.703. The method of claim 665, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.704. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation to raise an averagetemperature within the selected section to, or above, a temperature thatwill pyrolyze hydrocarbons within the selected section; producing amixture from the formation; and controlling an atomic hydrogen to carbonratio of the produced mixture to be greater than about 1.7 bycontrolling average pressure and average temperature in the selectedsection such that the average pressure in the selected section isgreater than the pressure (p) set forth in the following equation for anassessed average temperature (T) in the selected section: =e^([−38000/T+61]) where p is measured in psia and T is measured in °Kelvin.
 705. The method of claim 704, wherein the atomic hydrogen tocarbon ratio of the produced mixture is controlled to be greater thanabout 1.8, and wherein the equation is: p=e ^([−13000/T+24]).
 706. Themethod of claim 704, wherein the atomic hydrogen to carbon ratio of theproduced mixture is controlled to be greater than about 1.9, and whereinthe equation is: p=e ^([−8000/T+18]).
 707. The method of claim 704,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 708. The method of claim 704, wherein the one or more heatsources comprise electrical heaters.
 709. The method of claim 704,wherein the one or more heat sources comprise surface burners.
 710. Themethod of claim 704, wherein the one or more heat sources compriseflameless distributed combustors.
 711. The method of claim 704, whereinthe one or more heat sources comprise natural distributed combustors.712. The method of claim 704, further comprising controlling atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.713. The method of claim 712, wherein controlling the temperaturecomprises maintaining a temperature within the selected section within apyrolysis temperature range.
 714. The method of claim 704, furthercomprising controlling the heat such that an average heating rate of theselected section is less than about 1° C. per day during pyrolysis. 715.The method of claim 704, wherein providing heat from the one or moreheat sources to at least the portion of formation comprises: heating aselected volume (V) of the coal formation from the one or more heatsources, wherein the formation has an average heat capacity (C_(v)), andwherein the heating pyrolyzes at least some hydrocarbons within theselected volume of the formation; and wherein heating energy/dayprovided to the volume is equal to or less than Pwr, wherein Pwr iscalculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is theheating energy/day, h is an average heating rate of the formation, ρ_(B)is formation bulk density, and wherein the heating rate is less thanabout 10° C./day.
 716. The method of claim 704, wherein allowing theheat to transfer comprises transferring heat substantially byconduction.
 717. The method of claim 704, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 718. The method of claim704, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 719. The method of claim704, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 720. The method of claim 704,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 721. The method of claim 704,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 722. The method ofclaim 704, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 723.The method of claim 704, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 724. The method of claim 704, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 725. The method of claim 704, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 726. The method of claim 704, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 727. The method of claim 704, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 728. The method of claim 704, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 729. The method of claim 704, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.730. The method of claim 704, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 731. Themethod of claim 704, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 732. The method of claim 704, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 733. The method of claim 704, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 734. The method of claim 704, wherein the partialpressure of H₂ is measured when the mixture is at a production well.735. The method of claim 704, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 736. The methodof claim 704, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.737. The method of claim 704, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 738. The method of claim 704, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 739. Themethod of claim 704, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 740. The method of claim 704, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 741.The method of claim 704, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 742. The method of claim 704, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 743. The method of claim 704,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 744.The method of claim 704, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 745. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least one portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; controlling a pressure-temperaturerelationship within at least the selected section of the formation byselected energy input into the one or more heat sources and by pressurerelease from the selected section through wellbores of the one or moreheat sources; and producing a mixture from the formation.
 746. Themethod of claim 745, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 747. The method of claim 745, whereinthe one or more heat sources comprise at least two heat sources. 748.The method of claim 745, wherein the one or more heat sources comprisesurface burners.
 749. The method of claim 745, wherein the one or moreheat sources comprise flameless distributed combustors.
 750. The methodof claim 745, wherein the one or more heat sources comprise naturaldistributed combustors.
 751. The method of claim 745, further comprisingcontrolling the pressure-temperature relationship by controlling a rateof removal of fluid from the formation.
 752. The method of claim 745,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 753. The method of claim 745, wherein providing heat from theone or more heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 754. The method of claim 745, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 755. The method of claim 745, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 756. The method of claim745, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 757. The method of claim745, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 758. The method of claim 745,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 759. The method of claim 745,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 760. The method ofclaim 745, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 761.The method of claim 745, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 762. The method of claim 745, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 763. The method of claim 745, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 764. The method of claim 745, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 765. The method of claim 745, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 766. The method of claim 745, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 767. The method of claim 745, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.768. The method of claim 745, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 769. Themethod of claim 745, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 770. The method of claim 745, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 771. The method of claim 745, further comprising controllinga pressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 772. The method of claim 745, further comprising controllingformation conditions to produce a mixture of hydrocarbon fluids and H₂,wherein the partial pressure of H₂ within the mixture is greater thanabout 0.5 bar.
 773. The method of claim 745, further comprisingcontrolling formation conditions to produce a mixture of condensablehydrocarbons and H₂, wherein a partial pressure of H₂ within the mixtureis greater than about 0.5 bar.
 774. The method of claim 745, wherein thepartial pressure of H₂ is measured when the mixture is at a productionwell.
 775. The method of claim 745, further comprising altering apressure within the formation to inhibit production of hydrocarbons fromthe formation having carbon numbers greater than about
 25. 776. Themethod of claim 745, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.777. The method of claim 745, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 778. The method of claim 745, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 779. Themethod of claim 745, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 780. The method of claim 745, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 781.The method of claim 745, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 782. The method of claim 745, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 783. The method of claim 745,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 784.The method of claim 745, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 785. A method oftreating a coal formation in situ, comprising: heating a selected volume(V) of the coal formation, wherein formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 786. The method of claim 785, whereinheating a selected volume comprises heating with an electrical heater.787. The method of claim 785, wherein heating a selected volumecomprises heating with a surface burner.
 788. The method of claim 785,wherein heating a selected volume comprises heating with a flamelessdistributed combustor.
 789. The method of claim 785, wherein heating aselected volume comprises heating with a natural distributed combustors.790. The method of claim 785, further comprising controlling a pressureand a temperature within at least a majority of the selected volume ofthe formation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.791. The method of claim 785, further comprising controlling the heatingsuch that an average heating rate of the selected volume is less thanabout 1° C. per day during pyrolysis.
 792. The method of claim 785,wherein a value for C_(v) is determined as an average heat capacity oftwo or more samples taken from the coal formation.
 793. The method ofclaim 785, wherein heating the selected volume comprises transferringheat substantially by conduction.
 794. The method of claim 785, whereinheating the selected volume comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 795. The method of claim785, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 796. The method of claim785, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 797. The method of claim 785,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 798. The method of claim 785,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 799. The method ofclaim 785, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 800.The method of claim 785, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 801. The method of claim 785, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 802. The method of claim 785, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 803. The method of claim 785, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 804. The method of claim 785, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 805. The method of claim 785, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 806. The method of claim 785, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.807. The method of claim 785, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 808. Themethod of claim 785, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 809. The method of claim 785, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to produce fertilizer810. The method of claim 785, further comprising controlling a pressurewithin at least a majority of the selected volume of the formation,wherein the controlled pressure is at least about 2.0 bar absolute. 811.The method of claim 785, further comprising controlling formationconditions to produce a mixture from the formation comprisingcondensable hydrocarbons and H₂, wherein a partial pressure of H₂ withinthe mixture is greater than about 0.5 bar.
 812. The method of claim 785,wherein the partial pressure of H₂ is measured when the mixture is at aproduction well.
 813. The method of claim 785, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 814. The method of claim 785, wherein controlling formationconditions comprises recirculating a portion of hydrogen from themixture into the formation.
 815. The method of claim 785, furthercomprising: providing hydrogen (H₂) to the heated volume to hydrogenatehydrocarbons within the volume; and heating a portion of the volume withheat from hydrogenation.
 816. The method of claim 785, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 817. The method of claim 785, further comprising increasing apermeability of a majority of the selected volume to greater than about100 millidarcy.
 818. The method of claim 785, further comprisingsubstantially uniformly increasing a permeability of a majority of theselected volume.
 819. The method of claim 785, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 820. The methodof claim 785, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 821. The methodof claim 785, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.822. The method of claim 785, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.823. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation to raise an averagetemperature within the selected section to, or above, a temperature thatwill pyrolyze hydrocarbons within the selected section; controlling heatoutput from the one or more heat sources such that an average heatingrate of the selected section rises by less than about 3° C. per day whenthe average temperature of the selected section is at, or above, thetemperature that will pyrolyze hydrocarbons within the selected section;and producing a mixture from the formation.
 824. The method of claim823, controlling heat output comprises: raising the average temperaturewithin the selected section to a first temperature that is at or above aminimum pyrolysis temperature of hydrocarbons within the formation;limiting energy input into the one or more heat sources to inhibitincrease in temperature of the selected section; and increasing energyinput into the formation to raise an average temperature of the selectedsection above the first temperature when production of formation fluiddeclines below a desired production rate.
 825. The method of claim 823,controlling heat output comprises: raising the average temperaturewithin the selected section to a first temperature that is at or above aminimum pyrolysis temperature of hydrocarbons within the formation;limiting energy input into the one or more heat sources to inhibitincrease in temperature of the selected section; and increasing energyinput into the formation to raise an average temperature of the selectedsection above the first temperature when quality of formation fluidproduced from the formation falls below a desired quality.
 826. Themethod of claim 823, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section.
 827. The method of claim 823, wherein the one or moreheat sources comprise electrical heaters.
 828. The method of claim 823,wherein the one or more heat sources comprise surface burners.
 829. Themethod of claim 823, wherein the one or more heat sources compriseflameless distributed combustors.
 830. The method of claim 823, whereinthe one or more heat sources comprise natural distributed combustors.831. The method of claim 823, further comprising controlling a pressureand a temperature within at least a majority of the selected section ofthe formation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.832. The method of claim 823, wherein the heat is controlled that anaverage heating rate of the selected section is less than about 1.5° C.per day during pyrolysis.
 833. The method of claim 823, wherein the heatis controlled that an average heating rate of the selected section isless than about 1° C. per day during pyrolysis.
 834. The method of claim823, wherein providing heat from the one or more heat sources to atleast the portion of formation comprises: heating a selected volume (V)of the coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density.835. The method of claim 823, wherein allowing the heat to transfercomprises transferring heat substantially by conduction.
 836. The methodof claim 823, wherein providing heat from the one or more heat sourcescomprises heating the selected section such that a thermal conductivityof at least a portion of the selected section is greater than about 0.5W/(m° C.).
 837. The method of claim 823, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 838. The method of claim 823, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 839.The method of claim 823, wherein the produced mixture comprisescondensable hydrocarbons, wherein the condensable hydrocarbons have anolefin content is less than about 2.5% by weight of the condensablehydrocarbons, and wherein the olefin content is greater than about 0.1%by weight of the condensable hydrocarbons.
 840. The method of claim 823,wherein the produced mixture comprises non-condensable hydrocarbons,wherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons is less than about 0.15, and wherein the ratio of ethene toethane is greater than about 0.001.
 841. The method of claim 823,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons is less than about 0.10 and wherein the ratio of ethene toethane is greater than about 0.001.
 842. The method of claim 823,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons is less than about 0.05 and wherein the ratio of ethene toethane is greater than about 0.001.
 843. The method of claim 823,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is nitrogen.
 844. The method ofclaim 823, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 845. Themethod of claim 823, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 846. Themethod of claim 823, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 847. Themethod of claim 823, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 848. The method ofclaim 823, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 849. The method of claim 823, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 850. The methodof claim 823, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 851. The method of claim823, wherein the produced mixture comprises a non-condensable component,wherein the non-condensable component comprises hydrogen, wherein thehydrogen is greater than about 10% by volume of the non-condensablecomponent, and wherein the hydrogen is less than about 80% by volume ofthe non-condensable component.
 852. The method of claim 823, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 853. The method of claim823, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 854. The method of claim 823,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 855. The method of claim 823,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 856. The method ofclaim 823, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 857. The method of claim 823, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 858. The method of claim 823, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 859. The method of claim 823, furthercomprising: providing H₂ to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 860. The method of claim 823, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 861. The method of claim 823, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 862. The methodof claim 823, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 863. The method of claim 823, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 864. The methodof claim 823, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 865. The methodof claim 823, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.866. The method of claim 823, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.867. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; to heat a selected section of the formation to an averagetemperature above about 270 C; allowing the heat to transfer from theone or more heat sources to the selected section of the formation;controlling the heat from the one or more heat sources such that anaverage heating rate of the selected section is less than about 3° C.per day during pyrolysis; and producing a mixture from the formation.868. The method of claim 867, wherein the one or more heat sourcescomprise at least two heat sources, and wherein superposition of heatfrom at least the two heat sources pyrolyzes at least some hydrocarbonswithin the selected section of the formation.
 869. The method of claim867, wherein the one or more heat sources comprise electrical heaters.870. The method of claim 867, further comprising supplying electricityto the electrical heaters substantially during non-peak hours.
 871. Themethod of claim 867, wherein the one or more heat sources comprisesurface burners.
 872. The method of claim 867, wherein the one or moreheat sources comprise flameless distributed combustors.
 873. The methodof claim 867, wherein the one or more heat sources comprise naturaldistributed combustors.
 874. The method of claim 867, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 875. The method of claim 867,wherein the heat is further controlled such that an average heating rateof the selected section is less than about 3° C./day until production ofcondensable hydrocarbons substantially ceases.
 876. The method of claim867, wherein the heat is further controlled that an average heating rateof the selected section is less than about 1.5° C. per day duringpyrolysis.
 877. The method of claim 867, wherein the heat is furthercontrolled such that an average heating rate of the selected section isless than about 1° C. per day during pyrolysis.
 878. The method of claim867, wherein providing heat from the one or more heat sources to atleast the portion of formation comprises: heating a selected volume (V)of the coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density.879. The method of claim 867, wherein allowing the heat to transfercomprises transferring heat substantially by conduction.
 880. The methodof claim 867, wherein providing heat from the one or more heat sourcescomprises heating the selected section such that a thermal conductivityof at least a portion of the selected section is greater than about 0.5W/(m° C.).
 881. The method of claim 867, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 882. The method of claim 867, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 883.The method of claim 867, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 884. Themethod of claim 867, wherein the produced mixture comprisesnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons is less than about 0.15, and whereinthe ratio of ethene to ethane is greater than about 0.001.
 885. Themethod of claim 867, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 886.The method of claim 867, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 887. The method of claim 867, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 888. The method of claim 867, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 889. The method of claim 867, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 890. The method of claim 867, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 891. The method of claim 867, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 892. The method of claim 867, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.893. The method of claim 867, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component.
 894. Themethod of claim 867, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 895. The method of claim 867, wherein the produced mixturecomprises ammonia, and wherein the ammonia is used to producefertilizer.
 896. The method of claim 867, further comprising controllinga pressure within at least a majority of the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 897. The method of claim 867, further comprising controllingformation conditions to produce a mixture of condensable hydrocarbonsand H₂, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 898. The method of claim 897, wherein the partialpressure of H₂ is measured when the mixture is at a production well.899. The method of claim 867, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 900. The methodof claim 867, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.901. The method of claim 867, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 902. The method of claim 867, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 903. Themethod of claim 867, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 904. The method of claim 867, whereinallowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 905.The method of claim 867, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 906. The method of claim 867, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 907. The method of claim 867,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 908.The method of claim 867, further comprising providing heat from three ormore heat sources to at least a portion of the formation, wherein threeor more of the heat sources are located in the formation in a unit ofheat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 909. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation; producing a mixture from the formation throughat least one production well; monitoring a temperature at or in theproduction well; and controlling heat input to raise the monitoredtemperature at a rate of less than about 3° C. per day.
 910. The methodof claim 909, wherein the one or more heat sources comprise at least twoheat sources, and wherein superposition of heat from at least the twoheat sources pyrolyzes at least some hydrocarbons within the selectedsection of the formation.
 911. The method of claim 909, wherein the oneor more heat sources comprise electrical heaters.
 912. The method ofclaim 909, wherein the one or more heat sources comprise surfaceburners.
 913. The method of claim 909, wherein the one or more heatsources comprise flameless distributed combustors.
 914. The method ofclaim 909, wherein the one or more heat sources comprise naturaldistributed combustors.
 915. The method of claim 909, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 916. The method of claim 909,wherein the heat is controlled that an average heating rate of theselected section is less than about 1° C. per day during pyrolysis. 917.The method of claim 909, wherein providing heat from the one or moreheat sources to at least the portion of formation comprises: heating aselected volume (V) of the coal formation from the one or more heatsources, wherein the formation has an average heat capacity (C_(v)), andwherein the heating pyrolyzes at least some hydrocarbons within theselected volume of the formation; and wherein heating energy/dayprovided to the volume is equal to or less than Pwr, wherein Pwr iscalculated by the equation: Pwr=h*V*C _(v) *ρ _(B) wherein Pwr is theheating energy/day, h is an average heating rate of the formation, ρ_(B)is formation bulk density.
 918. The method of claim 909, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 919. The method of claim 909, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 920. The method of claim909, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 921. The method of claim909, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 922. The method of claim 909,wherein the produced mixture comprises non-condensable hydrocarbons,wherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons is less than about 0.15, and wherein the ratio of ethene toethane is greater than about 0.001.
 923. The method of claim 909,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is nitrogen.
 924. The method ofclaim 909, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 925. Themethod of claim 909, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 926. Themethod of claim 909, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 927. Themethod of claim 909, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 928. The method ofclaim 909, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 929. The method of claim 909, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 930. The methodof claim 909, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 931. The method of claim909, wherein the produced mixture comprises a non-condensable component,wherein the non-condensable component comprises hydrogen, wherein thehydrogen is greater than about 10% by volume of the non-condensablecomponent, and wherein the hydrogen is less than about 80% by volume ofthe non-condensable component.
 932. The method of claim 909, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 933. The method of claim909, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 934. The method of claim 909,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 935. The method of claim 909,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 936. The method ofclaim 935, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 937. The method of claim 909, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 938. The method of claim 909, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 939. The method of claim 909, furthercomprising: providing H₂ to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 940. The method of claim 909, wherein theproduced mixture comprises hydrogen and condensable hydrocarbons, themethod further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 941. The method of claim 909, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 942. The methodof claim 909, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 943. The method of claim 909, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 944. The methodof claim 909, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 945. The methodof claim 909, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.946. The method of claim 909, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.947. A method of treating a coal formation in situ, comprising: heatinga portion of the formation to a temperature sufficient to supportoxidation of hydrocarbons within the portion, wherein the portion islocated substantially adjacent to a wellbore; flowing an oxidant througha conduit positioned within the wellbore to a heat source zone withinthe portion, wherein the heat source zone supports an oxidation reactionbetween hydrocarbons and the oxidant; reacting a portion of the oxidantwith hydrocarbons to generate heat; and transferring generated heatsubstantially by conduction to a pyrolysis zone of the formation topyrolyze at least a portion of the hydrocarbons within the pyrolysiszone.
 948. The method of claim 947, wherein heating the portion of theformation comprises raising a temperature of the portion above about400° C.
 949. The method of claim 947, wherein the conduit comprisescritical flow orifices, the method further comprising flowing theoxidant through the critical flow orifices to the heat source zone. 950.The method of claim 947, further comprising removing reaction productsfrom the heat source zone through the wellbore.
 951. The method of claim947, further comprising removing excess oxidant from the heat sourcezone to inhibit transport of the oxidant to the pyrolysis zone.
 952. Themethod of claim 947, further comprising transporting the oxidant fromthe conduit to the heat source zone substantially by diffusion.
 953. Themethod of claim 947, further comprising heating the conduit withreaction products being removed through the wellbore.
 954. The method ofclaim 947, wherein the oxidant comprises hydrogen peroxide.
 955. Themethod of claim 947, wherein the oxidant comprises air.
 956. The methodof claim 947, wherein the oxidant comprises a fluid substantially freeof nitrogen.
 957. The method of claim 947, further comprising limitingan amount of oxidant to maintain a temperature of the heat source zoneless than about 1200° C.
 958. The method of claim 947, wherein heatingthe portion of the formation comprises electrically heating theformation.
 959. The method of claim 947, wherein heating the portion ofthe formation comprises heating the portion using exhaust gases from asurface burner.
 960. The method of claim 947, wherein heating theportion of the formation comprises heating the portion with a flamelessdistributed combustor.
 961. The method of claim 947, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe pyrolysis zone, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.962. The method of claim 947, further comprising controlling the heatsuch that an average heating rate of the pyrolysis zone is less thanabout 1° C. per day during pyrolysis.
 963. The method of claim 947,wherein heating the portion comprises heating the pyrolysis zone suchthat a thermal conductivity of at least a portion of the pyrolysis zoneis greater than about 0.5 W/(m° C.).
 964. The method of claim 947,further comprising controlling a pressure within at least a majority ofthe pyrolysis zone of the formation, wherein the controlled pressure isat least about 2.0 bar absolute.
 965. The method of claim 947, furthercomprising: providing hydrogen (H₂) to the pyrolysis zone to hydrogenatehydrocarbons within the pyrolysis zone; and heating a portion of thepyrolysis zone with heat from hydrogenation.
 966. The method of claim947, wherein transferring generated heat comprises increasing apermeability of a majority of the pyrolysis zone to greater than about100 millidarcy.
 967. The method of claim 947, wherein transferringgenerated heat comprises substantially uniformly increasing apermeability of a majority of the pyrolysis zone.
 968. The method ofclaim 947, wherein the heating is controlled to yield greater than about60% by weight of condensable hydrocarbons, as measured by Fischer Assay.969. The method of claim 947, wherein the wellbore is located alongstrike to reduce pressure differentials along a heated length of thewellbore.
 970. The method of claim 947, wherein the wellbore is locatedalong strike to increase uniformity of heating along a heated length ofthe wellbore.
 971. The method of claim 947, wherein the wellbore islocated along strike to increase control of heating along a heatedlength of the wellbore.
 972. A method of treating a coal formation insitu, comprising: heating a portion of the formation to a temperaturesufficient to support reaction of hydrocarbons within the portion of theformation with an oxidant; flowing the oxidant into a conduit, andwherein the conduit is connected such that the oxidant can flow from theconduit to the hydrocarbons; allowing the oxidant and the hydrocarbonsto react to produce heat in a heat source zone; allowing heat totransfer from the heat source zone to a pyrolysis zone in the formationto pyrolyze at least a portion of the hydrocarbons within the pyrolysiszone; and removing reaction products such that the reaction products areinhibited from flowing from the heat source zone to the pyrolysis zone.973. The method of claim 972, wherein heating the portion of theformation comprises raising the temperature of the portion above about400° C.
 974. The method of claim 972, wherein heating the portion of theformation comprises electrically heating the formation.
 975. The methodof claim 972, wherein heating the portion of the formation comprisesheating the portion using exhaust gases from a surface burner.
 976. Themethod of claim 972, wherein the conduit comprises critical floworifices, the method further comprising flowing the oxidant through thecritical flow orifices to the heat source zone.
 977. The method of claim972, wherein the conduit is located within a wellbore, wherein removingreaction products comprises removing reaction products from the heatsource zone through the wellbore.
 978. The method of claim 972, furthercomprising removing excess oxidant from the heat source zone to inhibittransport of the oxidant to the pyrolysis zone.
 979. The method of claim972, further comprising transporting the oxidant from the conduit to theheat source zone substantially by diffusion.
 980. The method of claim972, wherein the conduit is located within a wellbore, the methodfurther comprising heating the conduit with reaction products beingremoved through the wellbore to raise a temperature of the oxidantpassing through the conduit.
 981. The method of claim 972, wherein theoxidant comprises hydrogen peroxide.
 982. The method of claim 972,wherein the oxidant comprises air.
 983. The method of claim 972, whereinthe oxidant comprises a fluid substantially free of nitrogen.
 984. Themethod of claim 972, further comprising limiting an amount of oxidant tomaintain a temperature of the heat source zone less than about 1200° C.985. The method of claim 972, further comprising limiting an amount ofoxidant to maintain a temperature of the heat source zone at atemperature that inhibits production of oxides of nitrogen.
 986. Themethod of claim 972, wherein heating a portion of the formation to atemperature sufficient to support oxidation of hydrocarbons within theportion further comprises heating with a flameless distributedcombustor.
 987. The method of claim 972, further comprising controllinga pressure and a temperature within at least a majority of the pyrolysiszone of the formation, wherein the pressure is controlled as a functionof temperature, or the temperature is controlled as a function ofpressure.
 988. The method of claim 972, further comprising controllingthe heat such that an average heating rate of the pyrolysis zone is lessthan about 1° C. per day during pyrolysis.
 989. The method of claim 972,wherein allowing the heat to transfer comprises transferring heatsubstantially by conduction.
 990. The method of claim 972, whereinallowing heat to transfer comprises heating the pyrolysis zone such thata thermal conductivity of at least a portion of the pyrolysis zone isgreater than about 0.5 W/(m° C.).
 991. The method of claim 972, furthercomprising controlling a pressure within at least a majority of thepyrolysis zone, wherein the controlled pressure is at least about 2.0bar absolute.
 992. The method of claim 972, further comprising:providing hydrogen (H₂) to the pyrolysis zone to hydrogenatehydrocarbons within the pyrolysis zone; and heating a portion of thepyrolysis zone with heat from hydrogenation.
 993. The method of claim972, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the pyrolysis zone to greater than about100 millidarcy.
 994. The method of claim 972, wherein allowing the heatto transfer comprises substantially uniformly increasing a permeabilityof a majority of the pyrolysis zone.
 995. The method of claim 972,further comprising controlling the heat to yield greater than about 60%by weight of condensable hydrocarbons, as measured by Fischer Assay.996. An in situ method for heating a coal formation, comprising: heatinga portion of the formation to a temperature sufficient to supportreaction of hydrocarbons within the portion of the formation with anoxidizing fluid, wherein the portion is located substantially adjacentto an opening in the formation; providing the oxidizing fluid to a heatsource zone in the formation; allowing the oxidizing gas to react withat least a portion of the hydrocarbons at the heat source zone togenerate heat in the heat source zone; and transferring the generatedheat substantially by conduction from the heat source zone to apyrolysis zone in the formation.
 997. The method of claim 996, furthercomprising transporting the oxidizing fluid through the heat source zoneby diffusion.
 998. The method of claim 996, further comprising directingat least a portion of the oxidizing fluid into the opening throughorifices of a conduit disposed in the opening.
 999. The method of claim996, further comprising controlling a flow of the oxidizing fluid withcritical flow orifices of a conduit disposed in the opening such that arate of oxidation is controlled.
 1000. The method of claim 996, whereina conduit is disposed within the opening, the method further comprisingremoving an oxidation product from the formation through the conduit.1001. The method of claim 996, wherein a conduit is disposed within theopening, the method further comprising removing an oxidation productfrom the formation through the conduit and transferring substantial heatfrom the oxidation product in the conduit to the oxidizing fluid in theconduit.
 1002. The method of claim 996, wherein a conduit is disposedwithin the opening, the method further comprising removing an oxidationproduct from the formation through the conduit, wherein a flow rate ofthe oxidizing fluid in the conduit is approximately equal to a flow rateof the oxidation product in the conduit.
 1003. The method of claim 996,wherein a conduit is disposed within the opening, the method furthercomprising removing an oxidation product from the formation through theconduit and controlling a pressure between the oxidizing fluid and theoxidation product in the conduit to reduce contamination of theoxidation product by the oxidizing fluid.
 1004. The method of claim 996,wherein a center conduit is disposed within an outer conduit, andwherein the outer conduit is disposed within the opening, the methodfurther comprising providing the oxidizing fluid into the openingthrough the center conduit and removing an oxidation product through theouter conduit.
 1005. The method of claim 996, wherein the heat sourcezone extends radially from the opening a width of less thanapproximately 0.15 m.
 1006. The method of claim 996, wherein heating theportion comprises applying electrical current to an electric heaterdisposed within the opening.
 1007. The method of claim 996, wherein thepyrolysis zone is substantially adjacent to the heat source zone. 1008.The method of claim 996, further comprising controlling a pressure and atemperature within at least a majority of the pyrolysis zone of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.1009. The method of claim 996, further comprising controlling the heatsuch that an average heating rate of the pyrolysis zone is less thanabout 1° C. per day during pyrolysis.
 1010. The method of claim 996,wherein allowing the heat to transfer comprises transferring heatsubstantially by conduction.
 1011. The method of claim 996, whereinallowing heat to transfer comprises heating the portion such that athermal conductivity of at least a portion of the pyrolysis zone isgreater than about 0.5 W/(m° C.).
 1012. The method of claim 996, furthercomprising controlling a pressure within at least a majority of thepyrolysis zone, wherein the controlled pressure is at least about 2.0bar absolute.
 1013. The method of claim 996, further comprising:providing hydrogen (H₂) to the pyrolysis zone to hydrogenatehydrocarbons within the pyrolysis zone; and heating a portion of thepyrolysis zone with heat from hydrogenation.
 1014. The method of claim996, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the pyrolysis zone to greater than about100 millidarcy.
 1015. The method of claim 996, wherein allowing the heatto transfer comprises substantially uniformly increasing a permeabilityof a majority of the pyrolysis zone.
 1016. The method of claim 996,further comprising controlling the heat to yield greater than about 60%by weight of condensable hydrocarbons, as measured by Fischer Assay.1017. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; producing a mixture fromthe formation; and maintaining an average temperature within theselected section above a minimum pyrolysis temperature and below avaporization temperature of hydrocarbons having carbon numbers greaterthan 25 to inhibit production of a substantial amount of hydrocarbonshaving carbon numbers greater than 25 in the mixture.
 1018. The methodof claim 1017, wherein the one or more heat sources comprise at leasttwo heat sources, and wherein superposition of heat from at least thetwo heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 1019. The method of claim 1017,wherein maintaining the average temperature within the selected sectioncomprises maintaining the temperature within a pyrolysis temperaturerange.
 1020. The method of claim 1017, wherein the one or more heatsources comprise electrical heaters.
 1021. The method of claim 1017,wherein the one or more heat sources comprise surface burners.
 1022. Themethod of claim 1017, wherein the one or more heat sources compriseflameless distributed combustors.
 1023. The method of claim 1017,wherein the one or more heat sources comprise natural distributedcombustors.
 1024. The method of claim 1017, wherein the minimumpyrolysis temperature is greater than about 270° C.
 1025. The method ofclaim 1017, wherein the vaporization temperature is less thanapproximately 450° C. at atmospheric pressure.
 1026. The method of claim1017, further comprising controlling a pressure and a temperature withinat least a majority of the selected section of the formation, whereinthe pressure is controlled as a function of temperature, or thetemperature is controlled as a function of pressure.
 1027. The method ofclaim 1017, further comprising controlling the heat such that an averageheating rate of the selected section is less than about 1° C. per dayduring pyrolysis.
 1028. The method of claim 1017, wherein providing heatfrom the one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1029. The method of claim 1017, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1030. The method of claim 1017, wherein providing heatfrom the one or more heat sources comprises heating the selectedformation such that a thermal conductivity of at least a portion of theselected section is greater than about 0.5 W/(m° C.).
 1031. The methodof claim 1017, wherein the produced mixture comprises condensablehydrocarbons having an API gravity of at least about 25°.
 1032. Themethod of claim 1017, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 1033. The method of claim1017, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe non-condensable hydrocarbons are olefins.
 1034. The method of claim1017, wherein the produced mixture comprises non-condensablehydrocarbons, wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons is less than about 0.15, and wherein theratio of ethene to ethane is greater than about 0.001.
 1035. The methodof claim 1017, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1036.The method of claim 1017, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1037. The method of claim 1017, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1038. The method of claim 1017, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1039. The method of claim 1017, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1040. The method of claim 1017, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1041. The method of claim 1017, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1042. The method of claim 1017, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1043. The method of claim 1017, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1044. The method of claim 1017, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1045. The method of claim1017, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1046. The method of claim 1017,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1047. The method of claim 1017,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 1048. The method ofclaim 1047, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 1049. The method of claim 1017, whereincontrolling formation conditions comprises recirculating a portion ofhydrogen from the mixture into the formation.
 1050. The method of claim1017, further comprising: providing hydrogen (H₂) to the heated sectionto hydrogenate hydrocarbons within the section; and heating a portion ofthe section with heat from hydrogenation.
 1051. The method of claim1017, wherein the produced mixture comprises hydrogen and condensablehydrocarbons, the method further comprising hydrogenating a portion ofthe produced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1052. The method of claim 1017, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1053. Themethod of claim 1017, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1054. The method of claim 1017, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1055. The methodof claim 1017, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1056. The methodof claim 1017, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1057. The method of claim 1017, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1058. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; controlling a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than 25; and producing a mixturefrom the formation.
 1059. The method of claim 1058, wherein the one ormore heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1060. The method of claim 1058, wherein the one or more heat sourcescomprise electrical heaters.
 1061. The method of claim 1058, wherein theone or more heat sources comprise surface burners.
 1062. The method ofclaim 1058, wherein the one or more heat sources comprise flamelessdistributed combustors.
 1063. The method of claim 1058, wherein the oneor more heat sources comprise natural distributed combustors.
 1064. Themethod of claim 1058, further comprising controlling a temperaturewithin at least a majority of the selected section of the formation,wherein the pressure is controlled as a function of temperature, or thetemperature is controlled as a function of pressure.
 1065. The method ofclaim 1064, wherein controlling the temperature comprises maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 1066. The method of claim 1058, further comprising controllingthe heat such that an average heating rate of the selected section isless than about 1° C. per day during pyrolysis.
 1067. The method ofclaim 1058, wherein providing heat from the one or more heat sources toat least the portion of formation comprises: heating a selected volume(V) of the coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density,and wherein the heating rate is less than about 10° C./day.
 1068. Themethod of claim 1058, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1069. The method of claim1058, wherein providing heat from the one or more heat sources comprisesheating the selected formation such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1070. The method of claim 1058, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 1071. The method of claim 1058, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 1072.The method of claim 1058, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 1073. Themethod of claim 1058, wherein the produced mixture comprisesnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons is less than about 0.15, and whereinthe ratio of ethene to ethane is greater than about 0.001.
 1074. Themethod of claim 1058, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1075.The method of claim 1058, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1076. The method of claim 1058, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1077. The method of claim 1058, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1078. The method of claim 1058, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1079. The method of claim 1058, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1080. The method of claim 1058, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1081. The method of claim 1058, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1082. The method of claim 1058, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1083. The method of claim 1058, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1084. The method of claim1058, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1085. The method of claim 1058,further comprising controlling the pressure within at least a majorityof the selected section of the formation, wherein the controlledpressure is at least about 2.0 bar absolute.
 1086. The method of claim1058, further comprising controlling formation conditions to produce amixture of condensable hydrocarbons and H₂, wherein a partial pressureof H₂ within the mixture is greater than about 0.5 bar.
 1087. The methodof claim 1086, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 1088. The method of claim 1058, whereincontrolling formation conditions comprises recirculating a portion ofhydrogen from the mixture into the formation.
 1089. The method of claim1058, further comprising: providing hydrogen (H₂) to the heated sectionto hydrogenate hydrocarbons within the section; and heating a portion ofthe section with heat from hydrogenation.
 1090. The method of claim1058, wherein the produced mixture comprises hydrogen and condensablehydrocarbons, the method further comprising hydrogenating a portion ofthe produced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1091. The method of claim 1058, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1092. Themethod of claim 1058, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1093. The method of claim 1058, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1094. The methodof claim 1058, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1095. The methodof claim 1058, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1096. The method of claim 1058, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1097. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 1098. The method of claim1097, wherein the one or more heat sources comprise at least two heatsources, and wherein superposition of heat from at least the two heatsources pyrolyzes at least some hydrocarbons within the selected sectionof the formation.
 1099. The method of claim 1097, wherein the one ormore heat sources comprise electrical heaters.
 1100. The method of claim1097, wherein the one or more heat sources comprise surface burners.1101. The method of claim 1097, wherein the one or more heat sourcescomprise flameless distributed combustors.
 1102. The method of claim1097, wherein the one or more heat sources comprise natural distributedcombustors.
 1103. The method of claim 1097, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1104. The method of claim 1097,wherein controlling the temperature comprises maintaining thetemperature within the selected section within a pyrolysis temperaturerange.
 1105. The method of claim 1097, further comprising controllingthe heat such that an average heating rate of the selected section isless than about 1° C. per day during pyrolysis.
 1106. The method ofclaim 1097, wherein providing heat from the one or more heat sources toat least the portion of formation comprises: heating a selected volume(V) of the coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density,and wherein the heating rate is less than about 10° C./day.
 1107. Themethod of claim 1097, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1108. The method of claim1097, wherein providing heat from the one or more heat sources comprisesheating the selected formation such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1109. The method of claim 1097, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 1110. The method of claim 1097, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 1111.The method of claim 1097, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 1112. Themethod of claim 1097, wherein the produced mixture comprisesnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons is less than about 0.15, and whereinthe ratio of ethene to ethane is greater than about 0.001.
 1113. Themethod of claim 1097, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1114.The method of claim 1097, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1115. The method of claim 1097, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1116. The method of claim 1097, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1117. The method of claim 1097, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1118. The method of claim 1097, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1119. The method of claim 1097, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1120. The method of claim 1097, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1121. The method of claim 1097, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1122. The method of claim 1097, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1123. The method of claim1097, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1124. The method of claim 1097,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1125. The method of claim 1097,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 1126. The method ofclaim 1125, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 1127. The method of claim 1097, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 1128. The method of claim 1097, whereincontrolling formation conditions comprises recirculating a portion ofhydrogen from the mixture into the formation.
 1129. The method of claim1097, further comprising: providing hydrogen (H₂) to the heated sectionto hydrogenate hydrocarbons within the section; and heating a portion ofthe section with heat from hydrogenation.
 1130. The method of claim1097, wherein the produced mixture comprises hydrogen and condensablehydrocarbons, the method further comprising hydrogenating a portion ofthe produced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1131. The method of claim 1097, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1132. Themethod of claim 1097, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1133. The method of claim 1097, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1134. The methodof claim 1097, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1135. The methodof claim 1097, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1136. The method of claim 1097, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1137. A method of treating a coal formation in situ, comprising: heatinga section of the formation to a pyrolysis temperature from at least afirst heat source, a second heat source and a third heat source, andwherein the first heat source, the second heat source and the third heatsource are located along a perimeter of the section; controlling heatinput to the first heat source, the second heat source and the thirdheat source to limit a heating rate of the section to a rate configuredto produce a mixture from the formation with an olefin content of lessthan about 15% by weight of condensable fluids (on a dry basis) withinthe produced mixture; and producing the mixture from the formationthrough a production well.
 1138. The method of claim 1137, whereinsuperposition of heat form the first heat source, second heat source,and third heat source pyrolyzes a portion of the hydrocarbons within theformation to fluids
 1139. The method of claim 1137, wherein thepyrolysis temperature is between about 270° C. and about 400° C. 1140.The method of claim 1137, wherein the first heat source is operated forless than about twenty four hours a day.
 1141. The method of claim 1137,wherein the first heat source comprises an electrical heater.
 1142. Themethod of claim 1137, wherein the first heat source comprises a surfaceburner.
 1143. The method of claim 1137, wherein the first heat sourcecomprises a flameless distributed combustor.
 1144. The method of claim1137, wherein the first heat source, second heat source and third heatsource are positioned substantially at apexes of an equilateraltriangle.
 1145. The method of claim 1137, wherein the production well islocated substantially at a geometrical center of the first heat source,second heat source, and third heat source.
 1146. The method of claim1137, further comprising a fourth heat source, fifth heat source, andsixth heat source located along the perimeter of the section.
 1147. Themethod of claim 1146, wherein the heat sources are located substantiallyat apexes of a regular hexagon.
 1148. The method of claim 1147, whereinthe production well is located substantially at a center of the hexagon.1149. The method of claim 1137, further comprising controlling apressure and a temperature within at least a majority of the section ofthe formation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.1150. The method of claim 1137, wherein controlling the temperaturecomprises maintaining the temperature within the selected section withina pyrolysis temperature range.
 1151. The method of claim 1137, furthercomprising controlling the heat such that an average heating rate of thesection is less than about 3° C. per day during pyrolysis.
 1152. Themethod of claim 1137, further comprising controlling the heat such thatan average heating rate of the section is less than about 1° C. per dayduring pyrolysis.
 1153. The method of claim 1137, wherein providing heatfrom the one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1154. The method of claim 1137, whereinheating the section of the formation comprises transferring heatsubstantially by conduction.
 1155. The method of claim 1137, whereinproviding heat from the one or more heat sources comprises heating thesection such that a thermal conductivity of at least a portion of thesection is greater than about 0.5 W/(m° C.).
 1156. The method of claim1137, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1157. The method of claim1137, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1158. The method of claim 1137,wherein the produced mixture comprises non-condensable hydrocarbons,wherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons is less than about 0.15, and wherein the ratio of ethene toethane is greater than about 0.001.
 1159. The method of claim 1137,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is nitrogen.
 1160. The method ofclaim 1137, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 1161. Themethod of claim 1137, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 1162. Themethod of claim 1137, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 1163. Themethod of claim 1137, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 1164. The method ofclaim 1137, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1165. The method of claim 1137, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 1166. The methodof claim 1137, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 1167. The method of claim1137, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 1168. The method ofclaim 1137, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia.1169. The method of claim 1137, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 1170.The method of claim 1137, further comprising controlling a pressurewithin at least a majority of the selected section of the formation,wherein the controlled pressure is at least about 2.0 bar absolute.1171. The method of claim 1137, further comprising controlling formationconditions to produce a mixture of condensable hydrocarbons and H₂,wherein a partial pressure of H₂ within the mixture is greater thanabout 0.5 bar.
 1172. The method of claim 1171, wherein the partialpressure of H₂ is measured when the mixture is at a production well.1173. The method of claim 1137, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 1174. The methodof claim 1137, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.1175. The method of claim 1137, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 1176. The method of claim 1137, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1177. Themethod of claim 1137, heating the section comprises increasing apermeability of a majority of the section to greater than about 100millidarcy.
 1178. The method of claim 1137, wherein heating the sectioncomprises substantially uniformly increasing a permeability of amajority of the section.
 1179. The method of claim 1137, furthercomprising controlling the heat to yield greater than about 60% byweight of condensable hydrocarbons, as measured by Fischer Assay. 1180.The method of claim 1137, wherein producing the mixture comprisesproducing the mixture in a production well, and wherein at least about 7heat sources are disposed in the formation for each production well.1181. The method of claim 1137, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, and wherein the unit of heat sourcescomprises a triangular pattern.
 1182. The method of claim 1137, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, wherein the unit ofheat sources comprises a triangular pattern, and wherein a plurality ofthe units are repeated over an area of the formation to form arepetitive pattern of units.
 1183. A method of treating a coal formationin situ, comprising: providing heat from one or more heat sources to atleast a portion of the formation; allowing the heat to transfer from theone or more heat sources to a selected section of the formation; andproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 1184. The method of claim 1183, wherein theone or more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1185. The method of claim 1183, wherein the one or more heat sourcescomprise electrical heaters.
 1186. The method of claim 1183, wherein theone or more heat sources comprise surface burners.
 1187. The method ofclaim 1183, wherein the one or more heat sources comprise flamelessdistributed combustors.
 1188. The method of claim 1183, wherein the oneor more heat sources comprise natural distributed combustors.
 1189. Themethod of claim 1183, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.1190. The method of claim 1189, wherein controlling the temperaturecomprises maintaining the temperature within the selected section withina pyrolysis temperature range.
 1191. The method of claim 1183, furthercomprising controlling the heat such that an average heating rate of theselected section is less than about 1° C. per day during pyrolysis.1192. The method of claim 1183, wherein providing heat from the one ormore heat sources to at least the portion of formation comprises:heating a selected volume (V) of the coal formation from the one or moreheat sources, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 1193. The method of claim 1183, wherein allowingthe heat to transfer comprises transferring heat substantially byconduction.
 1194. The method of claim 1183, wherein providing heat fromthe one or more heat sources comprises heating the selected formationsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1195. The method of claim1183, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1196. The method of claim1183, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1197. The method of claim 1183,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein about 0.1% by weight to about 15% by weight of thenon-condensable hydrocarbons are olefins.
 1198. The method of claim1183, wherein the produced mixture comprises non-condensablehydrocarbons, wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons is less than about 0.15, and wherein theratio of ethene to ethane is greater than about 0.001.
 1199. The methodof claim 1183, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 1200. Themethod of claim 1183, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 1201. Themethod of claim 1183, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 1202. Themethod of claim 1183, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 1203. The method ofclaim 1183, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1204. The method of claim 1183, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 1205. The methodof claim 1183, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 1206. The method of claim1183, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 1207. The method ofclaim 1183, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia.1208. The method of claim 1183, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 1209.The method of claim 1183, further comprising controlling a pressurewithin at least a majority of the selected section of the formation,wherein the controlled pressure is at least about 2.0 bar absolute.1210. The method of claim 1183, further comprising controlling formationconditions to produce a mixture of condensable hydrocarbons and H₂,wherein a partial pressure of H₂ within the mixture is greater thanabout 0.5 bar.
 1211. The method of claim 1211, wherein the partialpressure of H₂ is measured when the mixture is at a production well.1212. The method of claim 1183, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 1213. The methodof claim 1183, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.1214. The method of claim 1183, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 1215. The method of claim 1183, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1216. Themethod of claim 1183, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1217. The method of claim 1183,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1218.The method of claim 1183, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1219. The method of claim 1183, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1220. The method of claim 1183,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1221.The method of claim 1183, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1222. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; and producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 1223. Themethod of claim 1222, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 1224. The method of claim 1222,wherein the one or more heat sources comprise electrical heaters. 1225.The method of claim 1222, wherein the one or more heat sources comprisesurface burners.
 1226. The method of claim 1222, wherein the one or moreheat sources comprise flameless distributed combustors.
 1227. The methodof claim 1222, wherein the one or more heat sources comprise naturaldistributed combustors.
 1228. The method of claim 1222, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1229. The method of claim 1228,wherein controlling the temperature comprises maintaining thetemperature within the selected section within a pyrolysis temperaturerange.
 1230. The method of claim 1222, further comprising controllingthe heat such that an average heating rate of the selected section isless than about 1° C. per day during pyrolysis.
 1231. The method ofclaim 1222, wherein providing heat from the one or more heat sources toat least the portion of formation comprises: heating a selected volume(V) of the coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density,and wherein the heating rate is less than about 10° C./day.
 1232. Themethod of claim 1222, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1233. The method of claim1222, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1234. The method of claim 1222, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 1235. The method of claim 1222, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 1236.The method of claim 1222, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 1237. Themethod of claim 1222, wherein the produced mixture comprisesnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons is less than about 0.15, and whereinthe ratio of ethene to ethane is greater than about 0.001.
 1238. Themethod of claim 1222, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1239.The method of claim 1222, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1240. The method of claim 1222, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1241. The method of claim 1222, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1242. The method of claim 1222, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1243. The method of claim 1222, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1244. The method of claim 1222, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1245. The method of claim 1222, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1246. The method of claim 1222, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1247. The method of claim 1222, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1248. The method of claim1222, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1249. The method of claim 1222,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1250. The method of claim 1222,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 1251. The method ofclaim 1250, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 1252. The method of claim 1222, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 1253. The method of claim 1222, whereincontrolling formation conditions comprises recirculating a portion ofhydrogen from the mixture into the formation.
 1254. The method of claim1222, further comprising: providing hydrogen (H₂) to the heated sectionto hydrogenate hydrocarbons within the section; and heating a portion ofthe section with heat from hydrogenation.
 1255. The method of claim1222, wherein the produced mixture comprises hydrogen and condensablehydrocarbons, the method further comprising hydrogenating a portion ofthe produced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1256. The method of claim 1222, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1257. Themethod of claim 1222, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1258. The method of claim 1222, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1259. The methodof claim 1222, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1260. The methodof claim 1222, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1261. The method of claim 1222, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1262. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 1263. Themethod of claim 1262, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 1264. The method of claim 1262,wherein the one or more heat sources comprise electrical heaters. 1265.The method of claim 1262, wherein the one or more heat sources comprisesurface burners.
 1266. The method of claim 1262, wherein the one or moreheat sources comprise flameless distributed combustors.
 1267. The methodof claim 1262, wherein the one or more heat sources comprise naturaldistributed combustors.
 1268. The method of claim 1262, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1269. The method of claim 1268,wherein controlling the temperature comprises maintaining thetemperature within the selected section within a pyrolysis temperaturerange.
 1270. The method of claim 1262, further comprising controllingthe heat into such that an average heating rate of the selected sectionis less than about 1° C. per day during pyrolysis.
 1271. The method ofclaim 1262, wherein providing heat from the one or more heat sources toat least the portion of formation comprises: heating a selected volume(V) of the coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density,and wherein the heating rate is less than about 10° C./day.
 1272. Themethod of claim 1262, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1273. The method of claim1262, wherein providing heat from the one or more heat sources comprisesheating the selected formation such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1274. The method of claim 1262, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 1275. The method of claim 1262, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 1276.The method of claim 1262, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 1277. Themethod of claim 1262, wherein the produced mixture comprisesnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons is less than about 0.15, and whereinthe ratio of ethene to ethane is greater than about 0.001.
 1278. Themethod of claim 1262, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1279.The method of claim 1262, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1280. The method of claim 1262, wherein the produced mixturecomprises condensable hydrocarbons, wherein about 5% by weight to about30% by weight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.1281. The method of claim 1262, wherein the produced mixture comprisescondensable hydrocarbons, and wherein greater than about 20% by weightof the condensable hydrocarbons are aromatic compounds.
 1282. The methodof claim 1262, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1283. The method of claim 1262, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 1284. The methodof claim 1262, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 1285. The method of claim1262, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 1286. The method ofclaim 1262, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia1287. The method of claim 1262, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 1288.The method of claim 1262, further comprising controlling a pressurewithin at least a majority of the selected section of the formation,wherein the controlled pressure is at least about 2.0 bar absolute.1289. The method of claim 1262, further comprising controlling formationconditions to produce a mixture of condensable hydrocarbons and H₂,wherein a partial pressure of H₂ within the mixture is greater thanabout 0.5 bar.
 1290. The method of claim 1289, wherein the partialpressure of H₂ is measured when the mixture is at a production well.1291. The method of claim 1262, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 1292. The methodof claim 1262, wherein controlling formation conditions comprisesrecirculating a portion of hydrogen from the mixture into the formation.1293. The method of claim 1262, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 1294. The method of claim 1262, wherein the producedmixture comprises hydrogen and condensable hydrocarbons, the methodfurther comprising hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1295. Themethod of claim 1262, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1296. The method of claim 1262,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1297.The method of claim 1262, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1298. The method of claim 1262, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1299. The method of claim 1262,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1300.The method of claim 1262, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1301. A methodof treating a coal formation in situ, comprising: rising a temperatureof a first section of the formation with one or more heat sources to afirst pyrolysis temperature heating the first section to an upperpyrolysis temperature, wherein heat is supplied to the first section ata rate configured to inhibit olefin production; producing a firstmixture from the formation, wherein the first mixture comprisescondensable hydrocarbons and H₂; creating a second mixture from thefirst mixture, wherein the second mixture comprises a higherconcentration of H₂ than the first mixture; raising a temperature of asecond section of the formation with one or more heat sources to asecond pyrolysis temperature; providing a portion of the second mixtureto the second section; heating the second section to an upper pyrolysistemperature, wherein heat is supplied to the second section at a rateconfigured to inhibit olefin production; and producing a third mixturefrom the second section.
 1302. The method of claim 1301, whereincreating the second mixture comprises removing condensable hydrocarbonsfrom the first mixture.
 1303. The method of claim 1301, wherein creatingthe second mixture comprises removing water from the first mixture.1304. The method of claim 1301, wherein creating the second mixturecomprises removing carbon dioxide from the first mixture.
 1305. Themethod of claim 1301, wherein the first pyrolysis temperature is greaterthan about 270° C.
 1306. The method of claim 1301, wherein the secondpyrolysis temperature is greater than about 270° C.
 1307. The method ofclaim 1301, wherein the upper pyrolysis temperature is about 500° C.1308. The method of claim 1301, wherein the one or more heat sourcescomprise at least two heat sources, and wherein superposition of heatfrom at least the two heat sources pyrolyzes at least some hydrocarbonswithin the first or second selected section of the formation.
 1309. Themethod of claim 1301, wherein the one or more heat sources compriseelectrical heaters.
 1310. The method of claim 1301, wherein the one ormore heat sources comprise surface burners.
 1311. The method of claim1301, wherein the one or more heat sources comprise flamelessdistributed combustors.
 1312. The method of claim 1301, wherein the oneor more heat sources comprise natural distributed combustors.
 1313. Themethod of claim 1301, further comprising controlling a pressure and atemperature within at least a majority of the first section and thesecond section of the formation, wherein the pressure is controlled as afunction of temperature, or the temperature is controlled as a functionof pressure.
 1314. The method of claim 1301, further comprisingcontrolling the heat to the first and second sections such that anaverage heating rate of the first and second sections is less than about1° C. per day during pyrolysis.
 1315. The method of claim 1301, whereinheating the first and the second sections comprises: heating a selectedvolume (V) of the coal formation from the one or more heat sources,wherein the formation has an average heat capacity (C_(v)), and whereinthe heating pyrolyzes at least some hydrocarbons within the selectedvolume of the formation; and wherein heating energy/day provided to thevolume is equal to or less than Pwr, wherein Pwr is calculated by theequation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, his an average heating rate of the formation, ρ_(B) is formation bulkdensity, and wherein the heating rate is less than about 10° C./day.1316. The method of claim 1301, wherein heating the first and secondsections comprises transferring heat substantially by conduction. 1317.The method of claim 1301, wherein heating the first and second sectionscomprises heating the first and second sections such that a thermalconductivity of at least a portion of the first and second sections isgreater than about 0.5 W/(m° C.).
 1318. The method of claim 1301,wherein the first or third mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1319. The method of claim1301, wherein the first or third mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 1320. The method of claim1301, wherein the first or third mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.1321. The method of claim 1301, wherein the first or third mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 1322. The method of claim 1301, wherein thefirst or third mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 1323. The method of claim 1301,wherein the first or third mixture comprises condensable hydrocarbons,and wherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 1324. The method ofclaim 1301, wherein the first or third mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 1325. Themethod of claim 1301, wherein the first or third mixture comprisescondensable hydrocarbons, and wherein greater than about 20% by weightof the condensable hydrocarbons are aromatic compounds.
 1326. The methodof claim 1301, wherein the first or third mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1327. The method of claim 1301, wherein the first or thirdmixture comprises condensable hydrocarbons, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 1328.The method of claim 1301, wherein the first or third mixture comprisescondensable hydrocarbons, and wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons are cycloalkanes.
 1329. Themethod of claim 1301, wherein the first or third mixture comprises anon-condensable component, and wherein the non-condensable componentcomprises hydrogen, and wherein the hydrogen is greater than about 10%by volume of the non-condensable component and wherein the hydrogen isless than about 80% by volume of the non-condensable component. 1330.The method of claim 1301, wherein the first or third mixture comprisesammonia, and wherein greater than about 0.05% by weight of the producedmixture is ammonia.
 1331. The method of claim 1301, wherein the first orthird mixture comprises ammonia, and wherein the ammonia is used toproduce fertilizer.
 1332. The method of claim 1301, further comprisingcontrolling a pressure within at least a majority of the first or secondsections of the formation, wherein the controlled pressure is at leastabout 2.0 bar absolute.
 1333. The method of claim 1301, furthercomprising controlling formation conditions to produce a mixture ofcondensable hydrocarbons and H₂, wherein a partial pressure of H₂ withinthe mixture is greater than about 0.5 bar.
 1334. The method of claim1333, wherein the partial pressure of H₂ within a mixture is measuredwhen the mixture is at a production well.
 1335. The method of claim1301, further comprising altering a pressure within the formation toinhibit production of hydrocarbons from the formation having carbonnumbers greater than about
 25. 1336. The method of claim 1301, furthercomprising: providing hydrogen (H₂) to the first or second section tohydrogenate hydrocarbons within the first or second section; and heatinga portion of the first or second section with heat from hydrogenation.1337. The method of claim 1301, further comprising: producing hydrogenand condensable hydrocarbons from the formation; and hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 1338. The method of claim 1301, furthercomprising increasing a permeability of a majority of the first orsecond section to greater than about 100 millidarcy.
 1339. The method ofclaim 1301, further comprising substantially uniformly increasing apermeability of a majority of the first or second section.
 1340. Themethod of claim 1301, wherein the heating is controlled to yield greaterthan about 60% by weight of condensable hydrocarbons, as measured byFischer Assay.
 1341. The method of claim 1301, wherein producing thefirst or third mixture comprises producing the first or third mixture ina production well, and wherein at least about 7 heat sources aredisposed in the formation for each production well.
 1342. The method ofclaim 1301, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1343. The method of claim 1301, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1344. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; producing a mixture fromthe formation; and hydrogenating a portion of the produced mixture withH₂ produced from the formation.
 1345. The method of claim 1344, whereinthe one or more heat sources comprise at least two heat sources, andwherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 1346. The method of claim 1344, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 1347. The method of claim 1344, wherein the one ormore heat sources comprise electrical heaters.
 1348. The method of claim1344, wherein the one or more heat sources comprise surface burners.1349. The method of claim 1344, wherein the one or more heat sourcescomprise flameless distributed combustors.
 1350. The method of claim1344, wherein the one or more heat sources comprise natural distributedcombustors.
 1351. The method of claim 1344, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1352. The method of claim 1344,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1353. The method of claim 1344, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1354. The method of claim 1344, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1355. The method of claim 1344, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1356. The method of claim1344, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1357. The method of claim1344, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1358. The method of claim 1344,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1359. The method ofclaim 1344, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1360.The method of claim 1344, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1361. The method of claim 1344, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1362. The method of claim 1344, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1363. The method of claim 1344, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1364. The method of claim 1344, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1365. The method of claim 1344, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1366. The method of claim 1344, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1367. The method of claim 1344, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1368. The method of claim 1344, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1369. The method of claim1344, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1370. The method of claim 1344,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1371. The method of claim 1344,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1372. The method of claim 1344, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1373. The method of claim 1344, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1374. The method of claim 1344, further comprising: providinghydrogen (H₂) to the heated section to hydrogenate hydrocarbons withinthe section; and heating a portion of the section with heat fromhydrogenation.
 1375. The method of claim 1344, wherein allowing the heatto transfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 1376. The methodof claim 1344, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1377. The method of claim 1344, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1378. The methodof claim 1344, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1379. The methodof claim 1344, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1380. The method of claim 1344, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1381. A method of treating a coal formation in situ, comprising: heatinga first section of the formation; producing H₂ from the first section offormation; heating a second section of the formation; and recirculatinga portion of the H₂ from the first section into the second section ofthe formation to provide a reducing environment within the secondsection of the formation.
 1382. The method of claim 1381, whereinheating the first section or heating the second section comprisesheating with an electrical heater.
 1383. The method of claim 1381,wherein heating the first section or heating the second sectioncomprises heating with a surface burner.
 1384. The method of claim 1381,wherein heating the first section or heating the second sectioncomprises heating with a flameless distributed combustor.
 1385. Themethod of claim 1381, wherein heating the first section or heating thesecond section comprises heating with a natural distributed combustor.1386. The method of claim 1381, further comprising controlling apressure and a temperature within at least a majority of the first orsecond section of the formation, wherein the pressure is controlled as afunction of temperature, or the temperature is controlled as a functionof pressure.
 1387. The method of claim 1381, further comprisingcontrolling the heat such that an average heating rate of the first orsecond section is less than about 1° C. per day during pyrolysis. 1388.The method of claim 1381, wherein heating the first section or heatingthe second section further comprises: heating a selected volume (V) ofthe coal formation from the one or more heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C _(v)*ρ_(B) wherein Pwr is the heating energy/day, h is anaverage heating rate of the formation, ρ_(B) is formation bulk density,and wherein the heating rate is less than about 10° C./day.
 1389. Themethod of claim 1381, wherein heating the first section or heating thesecond section comprises transferring heat substantially by conduction.1390. The method of claim 1381, wherein heating the first section orheating the second section comprises heating the formation such that athermal conductivity of at least a portion of the first or secondsection is greater than about 0.5 W/(m° C.).
 1391. The method of claim1381, further comprising producing a mixture from the second section,wherein the produced mixture comprises condensable hydrocarbons havingan API gravity of at least about 25°.
 1392. The method of claim 1381,further comprising producing a mixture from the second section, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 0.1% by weight to about 15% by weight of the condensablehydrocarbons are olefins.
 1393. The method of claim 1381, furthercomprising producing a mixture from the second section, wherein theproduced mixture comprises non-condensable hydrocarbons, and wherein amolar ratio of ethene to ethane in the non-condensable hydrocarbonsranges from about 0.001 to about 0.15.
 1394. The method of claim 1381,further comprising producing a mixture from the second section, whereinthe produced mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 1395. The method of claim 1381,further comprising producing a mixture from the second section, whereinthe produced mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 1396. The method of claim 1381,further comprising producing a mixture from the second section, whereinthe produced mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 1397. The method of claim 1381,further comprising producing a mixture from the second section, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons comprise oxygen containing compounds, and wherein theoxygen containing compounds comprise phenols.
 1398. The method of claim1381, further comprising producing a mixture from the second section,wherein the produced mixture comprises condensable hydrocarbons, andwherein greater than about 20% by weight of the condensable hydrocarbonsare aromatic compounds.
 1399. The method of claim 1381, furthercomprising producing a mixture from the second section, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 5% by weight of the condensable hydrocarbons comprisesmulti-ring aromatics with more than two rings.
 1400. The method of claim1381, further comprising producing a mixture from the second section,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 0.3% by weight of the condensable hydrocarbonsare asphaltenes.
 1401. The method of claim 1381, further comprisingproducing a mixture from the second section, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1402. The method of claim 1381, further comprisingproducing a mixture from the second section, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1403. The method of claim 1381, furthercomprising producing a mixture from the second section, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1404. The method of claim1381, further comprising producing a mixture from the second section,wherein the produced mixture comprises ammonia, and wherein the ammoniais used to produce fertilizer.
 1405. The method of claim 1381, furthercomprising controlling a pressure within at least a majority of thefirst or second section of the formation, wherein the controlledpressure is at least about 2.0 bar absolute.
 1406. The method of claim1381, further comprising controlling formation conditions to produce amixture of condensable hydrocarbons and H₂, wherein a partial pressureof H₂ within the mixture is greater than about 0.5 bar.
 1407. The methodof claim 1406, wherein the partial pressure of H₂ within a mixture ismeasured when the mixture is at a production well.
 1408. The method ofclaim 1381, further comprising altering a pressure within the formationto inhibit production of hydrocarbons from the formation having carbonnumbers greater than about
 25. 1409. The method of claim 1381, furthercomprising: providing hydrogen (H₂) to the second section to hydrogenatehydrocarbons within the section; and heating a portion of the secondsection with heat from hydrogenation.
 1410. The method of claim 1381,further comprising: producing hydrogen and condensable hydrocarbons fromthe formation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1411. Themethod of claim 1381, wherein heating the first section or heating thesecond section comprises increasing a permeability of a majority of thefirst or second section, respectively, to greater than about 100millidarcy.
 1412. The method of claim 1381, wherein heating the firstsection or heating the second section comprises substantially uniformlyincreasing a permeability of a majority of the first or second section,respectively.
 1413. The method of claim 1381, further comprisescontrolling the heating of the first section or controlling the heat ofthe second section to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1414. The methodof claim 1381, further comprising producing a mixture from the formationin a production well, and wherein at least about 7 heat sources aredisposed in the formation for each production well.
 1415. The method ofclaim 1381, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1416. The method of claim 1381, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1417. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; producing a mixture fromthe formation; and controlling formation conditions such that themixture produced from the formation comprises condensable hydrocarbonsincluding H₂, wherein the partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 1418. The method of claim 1417, wherein theone or more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1419. The method of claim 1417, wherein controlling formation conditionscomprises maintaining a temperature within the selected section within apyrolysis temperature range.
 1420. The method of claim 1417, wherein theone or more heat sources comprise electrical heaters.
 1421. The methodof claim 1417, wherein the one or more heat sources comprise surfaceburners.
 1422. The method of claim 1417, wherein the one or more heatsources comprise flameless distributed combustors.
 1423. The method ofclaim 1417, wherein the one or more heat sources comprise naturaldistributed combustors.
 1424. The method of claim 1417, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1425. The method of claim 1417,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1426. The method of claim 1417, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1427. The method of claim 1417, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1428. The method of claim 1417, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1429. The method of claim1417, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1430. The method of claim1417, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1431. The method of claim 1417,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1432. The method ofclaim 1417, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1433.The method of claim 1417, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1434. The method of claim 1417, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1435. The method of claim 1417, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1436. The method of claim 1417, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1437. The method of claim 1417, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1438. The method of claim 1417, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1439. The method of claim 1417, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1440. The method of claim 1417, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1441. The method of claim 1417, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1442. The method of claim1417, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1443. The method of claim 1417,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1444. The method of claim 1417,further comprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 1445. The method of claim 1417, whereincontrolling formation conditions comprises recirculating a portion ofhydrogen from the mixture into the formation.
 1446. The method of claim1417, further comprising: providing hydrogen (H₂) to the heated sectionto hydrogenate hydrocarbons within the section; and heating a portion ofthe section with heat from hydrogenation.
 1447. The method of claim1417, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1448. The method of claim 1417, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1449. Themethod of claim 1417, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1450. The method of claim 1417, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1451. The methodof claim 1417, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1452. The methodof claim 1417, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1453. The method of claim 1417, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1454. The method of claim 1417, wherein the partial pressure of H₂within the mixture is measured when the mixture is at a production well.1455. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; maintaining a pressureof the selected section above atmospheric pressure to increase a partialpressure of H₂, as compared to the partial pressure of H₂ at atmosphericpressure, in at least a majority of the selected section; and producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons having an API gravity of at least about 25°.1456. The method of claim 1455, wherein the one or more heat sourcescomprise at least two heat sources, and wherein superposition of heatfrom at least the two heat sources pyrolyzes at least some hydrocarbonswithin the selected section of the formation.
 1457. The method of claim1455, further comprising maintaining a temperature within the selectedsection within a pyrolysis temperature range.
 1458. The method of claim1455, wherein the one or more heat sources comprise electrical heaters.1459. The method of claim 1455, wherein the one or more heat sourcescomprise surface burners.
 1460. The method of claim 1455, wherein theone or more heat sources comprise flameless distributed combustors.1461. The method of claim 1455, wherein the one or more heat sourcescomprise natural distributed combustors.
 1462. The method of claim 1455,further comprising controlling the pressure and a temperature within atleast a majority of the selected section of the formation, wherein thepressure is controlled as a function of temperature, or the temperatureis controlled as a function of pressure.
 1463. The method of claim 1455,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1464. The method of claim 1455, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1465. The method of claim 1455, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1466. The method of claim 1455, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1467. The method of claim1455, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1468. The method of claim 1455,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1469. The method ofclaim 1455, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1470.The method of claim 1455, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1471. The method of claim 1455, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1472. The method of claim 1455, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1473. The method of claim 1455, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1474. The method of claim 1455, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1475. The method of claim 1455, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1476. The method of claim 1455, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1477. The method of claim 1455, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1478. The method of claim 1455, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1479. The method of claim1455, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1480. The method of claim 1455,further comprising controlling the pressure within at least a majorityof the selected section of the formation, wherein the controlledpressure is at least about 2.0 bar absolute.
 1481. The method of claim1455, further comprising increasing the pressure of the selectedsection, to an upper limit of about 21 bar absolute, to increase anamount of non-condensable hydrocarbons produced from the formation.1482. The method of claim 1455, further comprising decreasing pressureof the selected section, to a lower limit of about atmospheric pressure,to increase an amount of condensable hydrocarbons produced from theformation.
 1483. The method of claim 1455, wherein the partial pressurecomprises a partial pressure based on properties measured at aproduction well.
 1484. The method of claim 1455, further comprisingaltering the pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1485. The method of claim 1455, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1486. The method of claim 1455, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1487. The method of claim 1455, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1488. Themethod of claim 1455, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1489. The method of claim 1455,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1490.The method of claim 1455, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1491. The method of claim 1455, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1492. The method of claim 1455,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1493.The method of claim 1455, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1494. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; providing H₂ to the formation toproduce a reducing environment in at least some of the formation;producing a mixture from the formation.
 1495. The method of claim 1494,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 1496. The method of claim 1494, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 1497. The method of claim 1494, further comprisingseparating a portion of hydrogen within the mixture and recirculatingthe portion into the formation.
 1498. The method of claim 1494, whereinthe one or more heat sources comprise electrical heaters.
 1499. Themethod of claim 1494, wherein the one or more heat sources comprisesurface burners.
 1500. The method of claim 1494, wherein the one or moreheat sources comprise flameless distributed combustors.
 1501. The methodof claim 1494, wherein the one or more heat sources comprise naturaldistributed combustors.
 1502. The method of claim 1494, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1503. The method of claim 1494,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1504. The method of claim 1494, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1505. The method of claim 1494, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1506. The method of claim 1494, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1507. The method of claim1494, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1508. The method of claim1494, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1509. The method of claim 1494,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1510. The method ofclaim 1494, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1511.The method of claim 1494, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1512. The method of claim 1494, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1513. The method of claim 1494, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1514. The method of claim 1494, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1515. The method of claim 1494, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1516. The method of claim 1494, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1517. The method of claim 1494, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1518. The method of claim 1494, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1519. The method of claim 1494, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1520. The method of claim1494, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1521. The method of claim 1494,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1522. The method of claim 1494,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1523. The method of claim 1494, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1524. The method of claim 1494, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1525. The method of claim 1494, wherein providing hydrogen (H₂) tothe formation further comprises: hydrogenating hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 1526. The method of claim 1494, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 1527. The method of claim1494, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 1528. The method of claim 1494, wherein allowing theheat to transfer comprises substantially uniformly increasing apermeability of a majority of the selected section.
 1529. The method ofclaim 1494, further comprising controlling the heat to yield greaterthan about 60% by weight of condensable hydrocarbons, as measured byFischer Assay.
 1530. The method of claim 1494, wherein producing themixture comprises producing the mixture in a production well, andwherein at least about 7 heat sources are disposed in the formation foreach production well.
 1531. The method of claim 1494, further comprisingproviding heat from three or more heat sources to at least a portion ofthe formation, wherein three or more of the heat sources are located inthe formation in a unit of heat sources, and wherein the unit of heatsources comprises a triangular pattern.
 1532. The method of claim 1494,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, whereinthe unit of heat sources comprises a triangular pattern, and wherein aplurality of the units are repeated over an area of the formation toform a repetitive pattern of units.
 1533. A method of treating a coalformation in situ, comprising: providing heat from one or more heatsources to at least a portion of the formation; allowing the heat totransfer from the one or more heat sources to a selected section of theformation; providing H₂ to the selected section to hydrogenatehydrocarbons within the selected section and to heat a portion of thesection with heat from the hydrogenation; and controlling heating of theselected section by controlling amounts of H₂ provided to the selectedsection.
 1534. The method of claim 1533, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation.
 1535. Themethod of claim 1533, further comprising maintaining a temperaturewithin the selected section within a pyrolysis temperature range. 1536.The method of claim 1533, wherein the one or more heat sources compriseelectrical heaters.
 1537. The method of claim 1533, wherein the one ormore heat sources comprise surface burners.
 1538. The method of claim1533, wherein the one or more heat sources comprise flamelessdistributed combustors.
 1539. The method of claim 1533, wherein the oneor more heat sources comprise natural distributed combustors.
 1540. Themethod of claim 1533, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.1541. The method of claim 1533, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 1542. The method of claim 1533,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 1543. The methodof claim 1533, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1544. The method of claim1533, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1545. The method of claim 1533, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons having an API gravity of at least about 25°.1546. The method of claim 1533, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 1547. The method of claim1533, further comprising producing a mixture from the formation, whereinthe produced mixture comprises non-condensable hydrocarbons, and whereina molar ratio of ethene to ethane in the non-condensable hydrocarbonsranges from about 0.001 to about 0.15.
 1548. The method of claim 1533,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 1549. The method of claim 1533,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 1550. The method of claim 1533,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 1551. The method of claim 1533,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1552. The method of claim 1533, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and wherein greater than about 20%by weight of the condensable hydrocarbons are aromatic compounds. 1553.The method of claim 1533, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1554. The method of claim 1533, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 0.3% by weight ofthe condensable hydrocarbons are asphaltenes.
 1555. The method of claim1533, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 1556. The method of claim 1533, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1557. The method of claim 1533, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 1558. The method of claim1533, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 1559. The method of claim 1533, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 1560. The method of claim 1533, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 1561. The method of claim 1560, wherein thepartial pressure of H₂ within the mixture is measured when the mixtureis at a production well.
 1562. The method of claim 1533, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 1563. The method of claim 1533, furthercomprising controlling formation conditions by recirculating a portionof hydrogen from a produced mixture into the formation.
 1564. The methodof claim 1533, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1565. The method of claim 1533, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1566. Themethod of claim 1533, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1567. The method of claim 1533, wherein the heating iscontrolled of claim 1533, further comprising producing a mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 1568. The method of claim1533, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1569.The method of claim 1533, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1570. An in situmethod for producing H₂ from a coal formation, comprising: providingheat from one or more heat sources to at least a portion of theformation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and producing a mixturefrom the formation, wherein a H₂ partial pressure within the mixture isgreater than about 0.5 bar.
 1571. The method of claim 1570, wherein theone or more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1572. The method of claim 1570, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 1573. The method of claim 1570, wherein the one or more heatsources comprise electrical heaters.
 1574. The method of claim 1570,wherein the one or more heat sources comprise surface burners.
 1575. Themethod of claim 1570, wherein the one or more heat sources compriseflameless distributed combustors.
 1576. The method of claim 1570,wherein the one or more heat sources comprise natural distributedcombustors.
 1577. The method of claim 1570, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1578. The method of claim 1570,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1579. The method of claim 1570, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1580. The method of claim 1570, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1581. The method of claim 1570, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1582. The method of claim1570, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1583. The method of claim1570, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1584. The method of claim 1570,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1585. The method ofclaim 1570, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1586.The method of claim 1570, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1587. The method of claim 1570, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1588. The method of claim 1570, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1589. The method of claim 1570, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1590. The method of claim 1570, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1591. The method of claim 1570, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1592. The method of claim 1570, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1593. The method of claim 1570, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1594. The method of claim 1570, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1595. The method of claim1570, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1596. The method of claim 1570,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1597. The method of claim 1570,further comprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 1598. The method of claim 1570, furthercomprising recirculating a portion of the hydrogen within the mixtureinto the formation.
 1599. The method of claim 1570, further comprisingcondensing a hydrocarbon component from the produced mixture andhydrogenating the condensed hydrocarbons with a portion of the hydrogen.1600. The method of claim 1570, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 1601. The method of claim 1570, wherein allowing the heatto transfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 1602. The methodof claim 1570, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1603. The method of claim 1570, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1604. The methodof claim 1570, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1605. The methodof claim 1570, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1606. The method of claim 1570, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1607. The method of claim 1570, wherein the partial pressure of H₂within the mixture is measured when the mixture is at a production well.1608. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; wherein the selectedsection has been selected for heating using an atomic hydrogen weightpercentage of at least a portion of hydrocarbons in the selectedsection, and wherein at least the portion of the hydrocarbons in theselected section comprises an atomic hydrogen weight percentage, whenmeasured on a dry, ash-free basis, of greater than about 4.0%; andproducing a mixture from the formation.
 1609. The method of claim 1608,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 1610. The method of claim 1608, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 1611. The method of claim 1608, wherein the one ormore heat sources comprise electrical heaters.
 1612. The method of claim1608, wherein the one or more heat sources comprise surface burners.1613. The method of claim 1608, wherein the one or more heat sourcescomprise flameless distributed combustors.
 1614. The method of claim1608, wherein the one or more heat sources comprise natural distributedcombustors.
 1615. The method of claim 1608, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1616. The method of claim 1608,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1617. The method of claim 1608, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1618. The method of claim 1608, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1619. The method of claim 1608, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1620. The method of claim1608, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1621. The method of claim1608, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1622. The method of claim 1608,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1623. The method ofclaim 1608, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1624.The method of claim 1608, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1625. The method of claim 1608, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1626. The method of claim 1608, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1627. The method of claim 1608, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1628. The method of claim 1608, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1629. The method of claim 1608, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1630. The method of claim 1608, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1631. The method of claim 1608, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1632. The method of claim 1608, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1633. The method of claim1608, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1634. The method of claim 1608,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1635. The method of claim 1608,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1636. The method of claim 1635, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1637. The method of claim 1608, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1638. The method of claim 1608, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1639. The method of claim 1608, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1640. The method of claim 1608, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1641. Themethod of claim 1608, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1642. The method of claim 1608,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1643.The method of claim 1608, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1644. The method of claim 1608, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1645. The method of claim 1608,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1646.The method of claim 1608, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1647. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein at least some hydrocarbonswithin the selected section have an initial atomic hydrogen weightpercentage of greater than about 4.0%; and producing a mixture from theformation.
 1648. The method of claim 1647, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation.
 1649. Themethod of claim 1647, further comprising maintaining a temperaturewithin the selected section within a pyrolysis temperature range. 1650.The method of claim 1647, wherein the one or more heat sources compriseelectrical heaters.
 1651. The method of claim 1647, wherein the one ormore heat sources comprise surface burners.
 1652. The method of claim1647, wherein the one or more heat sources comprise flamelessdistributed combustors.
 1653. The method of claim 1647, wherein the oneor more heat sources comprise natural distributed combustors.
 1654. Themethod of claim 1647, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.1655. The method of claim 1647, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 1656. The method of claim 1647,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10°C./day.
 1657. The methodof claim 1647, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1658. The method of claim1647, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1659. The method of claim 1647, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 1660. The method of claim 1647, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 1661.The method of claim 1647, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 1662. The method of claim 1647, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 1663. The method of claim 1647, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 1664. The method of claim 1647,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 1665. The method ofclaim 1647, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 1666. Themethod of claim 1647, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 1667. The method ofclaim 1647, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1668. The method of claim 1647, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 1669. The methodof claim 1647, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 1670. The method of claim1647, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 1671. The method ofclaim 1647, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia.1672. The method of claim 1647, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 1673.The method of claim 1647, further comprising controlling a pressurewithin at least a majority of the selected section of the formation,wherein the controlled pressure is at least about 2.0 bar absolute.1674. The method of claim 1647, further comprising controlling formationconditions to produce the mixture, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 1675. The method ofclaim 1674, wherein the partial pressure of H₂ within the mixture ismeasured when the mixture is at a production well.
 1676. The method ofclaim 1647, further comprising altering a pressure within the formationto inhibit production of hydrocarbons from the formation having carbonnumbers greater than about
 25. 1677. The method of claim 1647, furthercomprising controlling formation conditions by recirculating a portionof hydrogen from the mixture into the formation.
 1678. The method ofclaim 1647, further comprising: providing hydrogen (H₂) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 1679. The method ofclaim 1647, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1680. The method of claim 1647, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1681. Themethod of claim 1647, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1682. The method of claim 1647, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1683. The methodof claim 1647, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1684. The methodof claim 1647, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1685. The method of claim 1647, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1686. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; wherein the selectedsection has been selected for heating using vitrinite reflectance of atleast some hydrocarbons in the selected section, and wherein at least aportion of the hydrocarbons in the selected section comprises avitrinite reflectance of greater than about 0.3%; wherein at least aportion of the hydrocarbons in the selected section comprises avitrinite reflectance of less than about 4.5%; and producing a mixturefrom the formation.
 1687. The method of claim 1686, wherein the one ormore heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1688. The method of claim 1686, further comprising maintaining atemperature within the selected section within a pyrolysis temperature.1689. The method of claim 1686, wherein the vitrinite reflectance of atleast the portion of hydrocarbons within the selected section is betweenabout 0.47% and about 1.5% such that a majority of the produced mixturecomprises condensable hydrocarbons.
 1690. The method of claim 1686,wherein the vitrinite reflectance of at least the portion ofhydrocarbons within the selected section is between about 1.4% and about4.2% such that a majority of the produced mixture comprisesnon-condensable hydrocarbons.
 1691. The method of claim 1686, whereinthe one or more heat sources comprise electrical heaters.
 1692. Themethod of claim 1686, wherein the one or more heat sources comprisesurface burners.
 1693. The method of claim 1686, wherein the one or moreheat sources comprise flameless distributed combustors.
 1694. The methodof claim 1686, wherein the one or more heat sources comprise naturaldistributed combustors.
 1695. The method of claim 1686, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1696. The method of claim 1686,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1697. The method of claim 1686, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1698. The method of claim 1686, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1699. The method of claim 1686, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1700. The method of claim1686, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1701. The method of claim1686, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1702. The method of claim 1686,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1703. The method ofclaim 1686, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1704.The method of claim 1686, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1705. The method of claim 1686, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1706. The method of claim 1686, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1707. The method of claim 1686, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1708. The method of claim 1686, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1709. The method of claim 1686, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1710. The method of claim 1686, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1711. The method of claim 1686, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1712. The method of claim 1686, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1713. The method of claim1686, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1714. The method of claim 1686,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1715. The method of claim 1686,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1716. The method of claim 1715, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1717. The method of claim 1686, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1718. The method of claim 1686, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1719. The method of claim 1686, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1720. The method of claim 1686, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1721. Themethod of claim 1686, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1722. The method of claim 1686,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1723.The method of claim 1686, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1724. The method of claim 1686, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1725. The method of claim 1686,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1726.The method of claim 1686, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1727. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein the selected section has beenselected for heating using a total organic matter weight percentage ofat least a portion of the selected section, and wherein at least theportion of the selected section comprises a total organic matter weightpercentage, of at least about 5.0%; and producing a mixture from theformation.
 1728. The method of claim 1727, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation.
 1729. Themethod of claim 1727, further comprising maintaining a temperaturewithin the selected section within a pyrolysis temperature range. 1730.The method of claim 1727, wherein the one or more heat sources compriseelectrical heaters.
 1731. The method of claim 1727, wherein the one ormore heat sources comprise surface burners.
 1732. The method of claim1727, wherein the one or more heat sources comprise flamelessdistributed combustors.
 1733. The method of claim 1727, wherein the oneor more heat sources comprise natural distributed combustors.
 1734. Themethod of claim 1727, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.1735. The method of claim 1727, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 1736. The method of claim 1727,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 1737. The methodof claim 1727, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 1738. The method of claim1727, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 1739. The method of claim 1727, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 1740. The method of claim 1727, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 1741.The method of claim 1727, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 1742. The method of claim 1727, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 1743. The method of claim 1727, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 1744. The method of claim 1727,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 1745. The method ofclaim 1727, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 1746. Themethod of claim 1727, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 1747. The method ofclaim 1727, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 1748. The method of claim 1727, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 1749. The methodof claim 1727, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 1750. The method of claim1727, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 1751. The method ofclaim 1727, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia.1752. The method of claim 1727, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 1753.The method of claim 1727, further comprising controlling a pressurewithin at least a majority of the selected section of the formation,wherein the controlled pressure is at least about 2.0 bar absolute.1754. The method of claim 1727, further comprising controlling formationconditions to produce the mixture, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 1755. The method ofclaim 1754, wherein the partial pressure of H₂ within the mixture ismeasured when the mixture is at a production well.
 1756. The method ofclaim 1727, further comprising altering a pressure within the formationto inhibit production of hydrocarbons from the formation having carbonnumbers greater than about
 25. 1757. The method of claim 1727, furthercomprising controlling formation conditions by recirculating a portionof hydrogen from the mixture into the formation.
 1758. The method ofclaim 1727, further comprising: providing hydrogen (H₂) to the heatedsection to hydrogenate hydrocarbons within the section; and heating aportion of the section with heat from hydrogenation.
 1759. The method ofclaim 1727, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 1760. The method of claim 1727, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 1761. Themethod of claim 1727, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 1762. The method of claim 1727, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 1763. The methodof claim 1727, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 1764. The methodof claim 1727, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.1765. The method of claim 1727, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.1766. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; wherein at least somehydrocarbons within the selected section have an initial total organicmatter weight percentage of at least about 5.0%; and producing a mixturefrom the formation.
 1767. The method of claim 1766, wherein the one ormore heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1768. The method of claim 1766, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 1769. The method of claim 1766, wherein the one or more heatsources comprise electrical heaters.
 1770. The method of claim 1766,wherein the one or more heat sources comprise surface burners.
 1771. Themethod of claim 1766, wherein the one or more heat sources compriseflameless distributed combustors.
 1772. The method of claim 1766,wherein the one or more heat sources comprise natural distributedcombustors.
 1773. The method of claim 1766, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1774. The method of claim 1766,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1775. The method of claim 1766, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about ° C./day.
 1776. The method of claim 1766, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1777. The method of claim 1766, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1778. The method of claim1766, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1779. The method of claim1766, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1780. The method of claim 1766,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1781. The method ofclaim 1766, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1782.The method of claim 1766, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1783. The method of claim 1766, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1784. The method of claim 1766, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1785. The method of claim 1766, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1786. The method of claim 1766, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1787. The method of claim 1766, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1788. The method of claim 1766, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1789. The method of claim 1766, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1790. The method of claim 1766, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1791. The method of claim1766, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1792. The method of claim 1766,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1793. The method of claim 1766,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1794. The method of claim 1793, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1795. The method of claim 1766, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1796. The method of claim 1766, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1797. The method of claim 1766, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1798. The method of claim 1766, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1799. Themethod of claim 1766, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1800. The method of claim 1766,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1801.The method of claim 1766, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1802. The method of claim 1766, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1803. The method of claim 1766,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1804.The method of claim 1766, further comprising providing heat from threeor more, heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1805. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein the selected section has beenselected for heating using an atomic oxygen weight percentage of atleast a portion of hydrocarbons in the selected section, and wherein atleast a portion of the hydrocarbons in the selected section comprises anatomic oxygen weight percentage of less than about 15% when measured ona dry, ash free basis; and producing a mixture from the formation. 1806.The method of claim 1805, wherein the one or more heat sources compriseat least two heat sources, and wherein superposition of heat from atleast the two heat sources pyrolyzes at least some hydrocarbons withinthe selected section of the formation.
 1807. The method of claim 1805,further comprising maintaining a temperature within the selected sectionwithin a pyrolysis temperature range.
 1808. The method of claim 1805,wherein the one or more heat sources comprise electrical heaters. 1809.The method of claim 1805, wherein the one or more heat sources comprisesurface burners.
 1810. The method of claim 1805, wherein the one or moreheat sources comprise flameless distributed combustors.
 1811. The methodof claim 1805, wherein the one or more heat sources comprise naturaldistributed combustors.
 1812. The method of claim 1805, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1813. The method of claim 1805,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1814. The method of claim 1805, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1815. The method of claim 1805, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1816. The method of claim 1805, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1817. The method of claim1805, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1818. The method of claim1805, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1819. The method of claim 1805,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1820. The method ofclaim 1805, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1821.The method of claim 1805, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1822. The method of claim 1805, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1823. The method of claim 1805, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1824. The method of claim 1805, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1825. The method of claim 1805, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1826. The method of claim 1805, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1827. The method of claim 1805, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1828. The method of claim 1805, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1829. The method of claim 1805, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1830. The method of claim1805, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1831. The method of claim 1805,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1832. The method of claim 1805,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1833. The method of claim 1832, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1834. The method of claim 1805, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1835. The method of claim 1805, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1836. The method of claim 1805, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1837. The method of claim 1805, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1838. Themethod of claim 1805, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1839. The method of claim 1805,wherein allowing the heat to transfer further comprises substantiallyuniformly increasing a permeability of a majority of the selectedsection.
 1840. The method of claim 1805, further comprising controllingthe heat to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay.
 1841. The method of claim1805, wherein producing the mixture comprises producing the mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 1842. The method of claim1805, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1843.The method of claim 1805, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1844. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to a selected section of the formation;allowing the heat to transfer from the one or more heat sources to theselected section of the formation to pyrolyze hydrocarbon within theselected section; wherein at least some hydrocarbons within the selectedsection have an initial atomic oxygen weight percentage of less thanabout 15%; and producing a mixture from the formation.
 1845. The methodof claim 1844, wherein the one or more heat sources comprise at leasttwo heat sources, and wherein superposition of heat from at least thetwo heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 1846. The method of claim 1844,further comprising maintaining a temperature within the selected sectionwithin a pyrolysis temperature range
 1847. The method of claim 1844,wherein the one or more heat sources comprise electrical heaters. 1848.The method of claim 1844, wherein the one or more heat sources comprisesurface burners.
 1849. The method of claim 1844, wherein the one or moreheat sources comprise flameless distributed combustors.
 1850. The methodof claim 1844, wherein the one or more heat sources comprise naturaldistributed combustors.
 1851. The method of claim 1844, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1852. The method of claim 1844,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1853. The method of claim 1844, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1854. The method of claim 1844, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1855. The method of claim 1844, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1856. The method of claim1844, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1857. The method of claim1844, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1858. The method of claim 1844,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1859. The method ofclaim 1844, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1860.The method of claim 1844, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1861. The method of claim 1844, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1862. The method of claim 1844, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1863. The method of claim 1844, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1864. The method of claim 1844, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1865. The method of claim 1844, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1866. The method of claim 1844, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1867. The method of claim 1844, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1868. The method of claim 1844, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1869. The method of claim1844, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1870. The method of claim 1844,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1871. The method of claim 1844,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1872. The method of claim 1871, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1873. The method of claim 1844, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1874. The method of claim 1844, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1875. The method of claim 1844, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1876. The method of claim 1844, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1877. Themethod of claim 1844, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1878. The method of claim 1844,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1879.The method of claim 1844, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1880. The method of claim 1844, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1881. The method of claim 1844,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1882.The method of claim 1844, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1883. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein the selected section has beenselected for heating using an atomic hydrogen to carbon ratio of atleast a portion of hydrocarbons in the selected section, wherein atleast a portion of the hydrocarbons in the selected section comprises anatomic hydrogen to carbon ratio greater than about 0.70, and wherein theatomic hydrogen to carbon ratio is less than about 1.65; and producing amixture from the formation.
 1884. The method of claim 1883, wherein theone or more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1885. The method of claim 1883, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 1886. The method of claim 1883, wherein the one or more heatsources comprise electrical heaters.
 1887. The method of claim 1883,wherein the one or more heat sources comprise surface burners.
 1888. Themethod of claim 1883, wherein the one or more heat sources compriseflameless distributed combustors.
 1889. The method of claim 1883,wherein the one or more heat sources comprise natural distributedcombustors.
 1890. The method of claim 1883, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1891. The method of claim 1883,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1892. The method of claim 1883, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1893. The method of claim 1883, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1894. The method of claim 1883, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1895. The method of claim1883, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1896. The method of claim1883, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1897. The method of claim 1883,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1898. The method ofclaim 1883, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1899.The method of claim 1883, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1900. The method of claim 1883, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1901. The method of claim 1883, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1902. The method of claim 1883, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1903. The method of claim 1883, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1904. The method of claim 1883, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1905. The method of claim 1883, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1906. The method of claim 1883, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1907. The method of claim 1883, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1908. The method of claim1883, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1909. The method of claim 1883,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1910. The method of claim 1883,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1911. The method of claim 1910, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1912. The method of claim 1883, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1913. The method of claim 1883, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1914. The method of claim 1883, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1915. The method of claim 1883, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1916. Themethod of claim 1883, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1917. The method of claim 1883,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1918.The method of claim 1883, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1919. The method of claim 1883, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1920. The method of claim 1883,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1921.The method of claim 1883, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1922. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to a selected section of the formation;allowing the heat to transfer from the one or more heat sources to theselected section of the formation to pyrolyze hydrocarbons within theselected section; wherein at least some hydrocarbons within the selectedsection have an initial atomic hydrogen to carbon ratio greater thanabout 0.70; wherein the initial atomic hydrogen to carbon ration is lessthan about 1.65; and producing a mixture from the formation.
 1923. Themethod of claim 1922, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 1924. The method of claim 1922,further comprising maintaining a temperature within the selected sectionwithin a pyrolysis temperature range.
 1925. The method of claim 1922,wherein the one or more heat sources comprise electrical heaters. 1926.The method of claim 1922, wherein the one or more heat sources comprisesurface burners.
 1927. The method of claim 1922, wherein the one or moreheat sources comprise flameless distributed combustors.
 1928. The methodof claim 1922, wherein the one or more heat sources comprise naturaldistributed combustors.
 1929. The method of claim 1922, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1930. The method of claim 1922,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1931. The method of claim 1922, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1932. The method of claim 1922, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1933. The method of claim 1922, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1934. The method of claim1922, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1935. The method of claim1922, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1936. The method of claim 1922,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1937. The method ofclaim 1922, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1938.The method of claim 1922, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1939. The method of claim 1922, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1940. The method of claim 1922, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1941. The method of claim 1922, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1942. The method of claim 1922, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1943. The method of claim 1922, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1944. The method of claim 1922, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1945. The method of claim 1922, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1946. The method of claim 1922, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1947. The method of claim1922, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1948. The method of claim 1922,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1949. The method of claim 1922,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1950. The method of claim 1949, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1951. The method of claim 1922, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1952. The method of claim 1922, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1953. The method of claim 1922, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1954. The method of claim 1922, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1955. Themethod of claim 1922, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1956. The method of claim 1922,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 1957.The method of claim 1922, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 1958. The method of claim 1922, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 1959. The method of claim 1922,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1960.The method of claim 1922, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 1961. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein the selected section has beenselected for heating using an atomic oxygen to carbon ratio of at leasta portion of hydrocarbons in the selected section, wherein at least aportion of the hydrocarbons in the selected section comprises an atomicoxygen to carbon ratio greater than about 0.025, and wherein the atomicoxygen to carbon ratio of at least a portion of the hydrocarbons in theselected section is less than about 0.15 and producing a mixture fromthe formation.
 1962. The method of claim 1961, wherein the one or moreheat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.1963. The method of claim 1961, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 1964. The method of claim 1961, wherein the one or more heatsources comprise electrical heaters.
 1965. The method of claim 1961,wherein the one or more heat sources comprise surface burners.
 1966. Themethod of claim 1961, wherein the one or more heat sources compriseflameless distributed combustors.
 1967. The method of claim 1961,wherein the one or more heat sources comprise natural distributedcombustors.
 1968. The method of claim 1961, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 1969. The method of claim 1961,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 1970. The method of claim 1961, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 1971. The method of claim 1961, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 1972. The method of claim 1961, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 1973. The method of claim1961, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 1974. The method of claim1961, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 1975. The method of claim 1961,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 1976. The method ofclaim 1961, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 1977.The method of claim 1961, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 1978. The method of claim 1961, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 1979. The method of claim 1961, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 1980. The method of claim 1961, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 1981. The method of claim 1961, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 1982. The method of claim 1961, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 1983. The method of claim 1961, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 1984. The method of claim 1961, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 1985. The method of claim 1961, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 1986. The method of claim1961, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 1987. The method of claim 1961,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 1988. The method of claim 1961,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 1989. The method of claim 1988, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 1990. The method of claim 1961, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 1991. The method of claim 1961, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 1992. The method of claim 1961, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 1993. The method of claim 1961, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 1994. Themethod of claim 1961, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 1995. The method of claim 1961,wherein allowing the heat to transfer further comprises substantiallyuniformly increasing a permeability of a majority of the selectedsection.
 1996. The method of claim 1961, further comprising controllingthe heat to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay.
 1997. The method of claim1961, wherein producing the mixture comprises producing the mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 1998. The method of claim1961, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 1999.The method of claim 1961, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2000. A methodof treating a coal formation in situ, comprising providing heat from oneor more heat sources to a selected section of the formation; allowingthe heat to transfer from the one or more heat sources to the selectedsection of the formation to pyrolyze hydrocarbons within the selectedsection; wherein at least some hydrocarbons within the selected sectionhave an initial atomic oxygen to carbon ratio greater than about 0.025;wherein the initial atomic oxygen to carbon ratio is less than about0.15; and producing a mixture from the formation.
 2001. The method ofclaim 2000, wherein the one or more heat sources comprise at least twoheat sources, and wherein superposition of heat from at least the twoheat sources pyrolyzes at least some hydrocarbons within the selectedsection of the formation.
 2002. The method of claim 2000, furthercomprising maintaining a temperature within the selected section withina pyrolysis temperature range.
 2003. The method of claim 2000, whereinthe one or more heat sources comprise electrical heaters.
 2004. Themethod of claim 2000, wherein the one or more heat sources comprisesurface burners.
 2005. The method of claim 2000, wherein the one or moreheat sources comprise flameless distributed combustors.
 2006. The methodof claim 2000, wherein the one or more heat sources comprise naturaldistributed combustors.
 2007. The method of claim 2000, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2008. The method of claim 2000,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2009. The method of claim 2000, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2010. The method of claim 2000, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2011. The method of claim 2000, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2012. The method of claim2000, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2013. The method of claim2000, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2014. The method of claim 2000,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2015. The method ofclaim 2000, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2016.The method of claim 2000, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2017. The method of claim 2000, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2018. The method of claim 2000, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2019. The method of claim 2000, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2020. The method of claim 2000, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2021. The method of claim 2000, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2022. The method of claim 2000, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2023. The method of claim 2000, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2024. The method of claim 2000, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2025. The method of claim2000, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2026. The method of claim 2000,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2027. The method of claim 2000,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2028. The method of claim 2027, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2029. The method of claim 2000, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2030. The method of claim 2000, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2031. The method of claim 2000, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2032. The method of claim 2000, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2033. Themethod of claim 2000, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 2034. The method of claim 2000,wherein allowing the heat to transfer further comprises substantiallyuniformly increasing a permeability of a majority of the selectedsection.
 2035. The method of claim 2000, further comprising controllingthe heat to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay.
 2036. The method of claim2000, wherein producing the mixture comprises producing the mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 2037. The method of claim2000, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2038.The method of claim 2000, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2039. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein the selected section has beenselected for heating using a moisture content in the selected section,and wherein at least a portion of the selected section comprises amoisture content of less than about 15%; and producing a mixture fromthe formation.
 2040. The method of claim 2039, wherein the one or moreheat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.2041. The method of claim 2039, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 2042. The method of claim 2039, wherein the one or more heatsources comprise electrical heaters.
 2043. The method of claim 2039,wherein the one or more heat sources comprise surface burners.
 2044. Themethod of claim 2039, wherein the one or more heat sources compriseflameless distributed combustors.
 2045. The method of claim 2039,wherein the one or more heat sources comprise natural distributedcombustors.
 2046. The method of claim 2039, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2047. The method of claim 2039,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2048. The method of claim 2039, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2049. The method of claim 2039, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2050. The method of claim 2039, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2051. The method of claim2039, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2052. The method of claim2039, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2053. The method of claim 2039,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2054. The method ofclaim 2039, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2055.The method of claim 2039, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2056. The method of claim 2039, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2057. The method of claim 2039, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2058. The method of claim 2039, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2059. The method of claim 2039, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2060. The method of claim 2039, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2061. The method of claim 2039, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2062. The method of claim 2039, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2063. The method of claim 2039, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2064. The method of claim2039, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2065. The method of claim 2039,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2066. The method of claim 2039,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2067. The method of claim 2066, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2068. The method of claim 2039, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2069. The method of claim 2039, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2070. The method of claim 2039, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2071. The method of claim 2039, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2072. Themethod of claim 2039, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 2073. The method of claim 2039,wherein allowing the heat to transfer further comprises substantiallyuniformly increasing a permeability of a majority of the selectedsection.
 2074. The method of claim 2039, further comprising controllingthe heat to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay.
 2075. The method of claim2039, wherein producing the mixture comprises producing the mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 2076. The method of claim2039, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2077.The method of claim 2039, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2078. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to a selected section of the formation;allowing the heat to transfer from the one or more heat sources to theselected section of the formation; wherein at least a portion of theselected section has an initial moisture content of less than about 15%;and producing a mixture from the formation.
 2079. The method of claim2078, wherein the one or more heat sources comprise at least two heatsources, and wherein superposition of heat from at least the two heatsources pyrolyzes at least some hydrocarbons within the selected sectionof the formation.
 2080. The method of claim 2078, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 2081. The method of claim 2078, wherein the one ormore heat sources comprise electrical heaters.
 2082. The method of claim2078, wherein the one or more heat sources comprise surface burners.2083. The method of claim 2078, wherein the one or more heat sourcescomprise flameless distributed combustors.
 2084. The method of claim2078, wherein the one or more heat sources comprise natural distributedcombustors.
 2085. The method of claim 2078, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2086. The method of claim 2078,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2087. The method of claim 2078, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2088. The method of claim 2078, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2089. The method of claim 2078, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2090. The method of claim2078, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2091. The method of claim2078, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2092. The method of claim 2078,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2093. The method ofclaim 2078, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2094.The method of claim 2078, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2095. The method of claim 2078, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2096. The method of claim 2078, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2097. The method of claim 2078, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2098. The method of claim 2078, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2099. The method of claim 2078, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2100. The method of claim 2078, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2101. The method of claim 2078, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2102. The method of claim 2078, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2103. The method of claim2078, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2104. The method of claim 2078,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2105. The method of claim 2078,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2106. The method of claim 2105, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2107. The method of claim 2078, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2108. The method of claim 2078, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2109. The method of claim 2078, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2110. The method of claim 2078, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2111. Themethod of claim 2078, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 2112. The method of claim 2078,wherein allowing the heat to transfer further comprises substantiallyuniformly increasing a permeability of a majority of the selectedsection.
 2113. The method of claim 2078, further comprising controllingthe heat to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay.
 2114. The method of claim2078, wherein producing the mixture comprises producing the mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 2115. The method of claim2078, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2116.The method of claim 2078, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2117. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; wherein the selected section isheated in a reducing environment during at least a portion of the timethat the selected section is being heated; and producing a mixture fromthe formation.
 2118. The method of claim 2117, wherein the one or moreheat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.2119. The method of claim 2117, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 2120. The method of claim 2117, wherein the one or more heatsources comprise electrical heaters.
 2121. The method of claim 2117,wherein the one or more heat sources comprise surface burners.
 2122. Themethod of claim 2117, wherein the one or more heat sources compriseflameless distributed combustors.
 2123. The method of claim 2117,wherein the one or more heat sources comprise natural distributedcombustors.
 2124. The method of claim 2117, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2125. The method of claim 2117,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2126. The method of claim 2117, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2127. The method of claim 2117, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2128. The method of claim 2117, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2129. The method of claim2117, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2130. The method of claim2117, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2131. The method of claim 2117,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2132. The method ofclaim 2117, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2133.The method of claim 2117, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2134. The method of claim 2117, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2135. The method of claim 2117, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2136. The method of claim 2117, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2137. The method of claim 2117, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2138. The method of claim 2117, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2139. The method of claim 2117, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2140. The method of claim 2117, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2141. The method of claim 2117, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2142. The method of claim2117, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2143. The method of claim 2117,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2144. The method of claim 2117,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2145. The method of claim 2144, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2146. The method of claim 2117, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2147. The method of claim 2117, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2148. The method of claim 2117, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2149. The method of claim 2117, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2150. Themethod of claim 2117, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 2151. The method of claim 2117,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 2152.The method of claim 2117, further comprising controlling the heat toyield greater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 2153. The method of claim 2117, whereinproducing the mixture comprises producing the mixture in a productionwell, and wherein at least about 7 heat sources are disposed in theformation for each production well.
 2154. The method of claim 2117,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2155.The method of claim 2117, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2156. A methodof treating a coal formation in situ, comprising: heating a firstsection of the formation to produce a mixture from the formation;heating a second section of the formation; and recirculating a portionof the produced mixture from the first section into the second sectionof the formation to provide a reducing environment within the secondsection of the formation.
 2157. The method of claim 2156, furthercomprising maintaining a temperature within the first section or thesecond section within a pyrolysis temperature range.
 2158. The method ofclaim 2156, wherein heating the first or the second section comprisesheating with an electrical heater.
 2159. The method of claim 2156,wherein heating the first or the second section comprises heating with asurface burner.
 2160. The method of claim 2156, wherein heating thefirst or the second section comprises heating with a flamelessdistributed combustor.
 2161. The method of claim 2156, wherein heatingthe first or the second section comprises heating with a naturaldistributed combustor.
 2162. The method of claim 2156, furthercomprising controlling a pressure and a temperature within at least amajority of the first or second section of the formation, wherein thepressure is controlled as a function of temperature, or the temperatureis controlled as a function of pressure.
 2163. The method of claim 2156,further comprising controlling the heat such that an average heatingrate of the first or the second section is less than about 1° C. per dayduring pyrolysis.
 2164. The method of claim 2156, wherein heating thefirst or the second section comprises: heating a selected volume (V) ofthe coal formation from one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 2165. The methodof claim 2156, wherein heating the first or the second section comprisestransferring heat substantially by conduction.
 2166. The method of claim2156, wherein heating the first or the second section comprises heatingthe first or the second section such that a thermal conductivity of atleast a portion of the first or the second section is greater than about0.5 W/(m° C.).
 2167. The method of claim 2156, wherein the producedmixture comprises condensable hydrocarbons having an API gravity of atleast about 25°.
 2168. The method of claim 2156, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 0.1% byweight to about 15% by weight of the condensable hydrocarbons areolefins.
 2169. The method of claim 2156, wherein the produced mixturecomprises non-condensable hydrocarbons, and wherein a molar ratio ofethene to ethane in the non-condensable hydrocarbons ranges from about0.001 to about 0.15.
 2170. The method of claim 2156, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 2171. The method of claim 2156,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is oxygen.
 2172. The method ofclaim 2156, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 2173. Themethod of claim 2156, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 2174. Themethod of claim 2156, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2175. The method ofclaim 2156, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 2176. The method of claim 2156, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 2177. The methodof claim 2156, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 2178. The method of claim2156, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 2179. The method ofclaim 2156, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia.2180. The method of claim 2156, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 2181.The method of claim 2156, further comprising controlling a pressurewithin at least a majority of the first or second section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 2182. The method of claim 2156, further comprising controllingformation conditions to produce the mixture, wherein a partial pressureof H₂ within the mixture is greater than about 0.5 bar.
 2183. The methodof claim 2182, wherein the partial pressure of H₂ within the mixture ismeasured when the mixture is at a production well.
 2184. The method ofclaim 2156, further comprising altering a pressure within the formationto inhibit production of hydrocarbons from the formation having carbonnumbers greater than about
 25. 2185. The method of claim 2156, furthercomprising: providing hydrogen (H₂) to the first or second section tohydrogenate hydrocarbons within the first or second section; and heatinga portion of the first or second section with heat from hydrogenation.2186. The method of claim 2156, further comprising: producing hydrogenand condensable hydrocarbons from the formation; and hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 2187. The method of claim 2156, whereinheating the first or the second section comprises increasing apermeability of a majority of the first or the second section to greaterthan about 100 millidarcy.
 2188. The method of claim 2156, whereinheating the first or the second section comprises substantiallyuniformly increasing a permeability of a majority of the first or thesecond section.
 2189. The method of claim 2156, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 2190. The methodof claim 2156, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 2191. The methodof claim 2156, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2192. The method of claim 2156, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2193. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; and allowing the heat to transfer from the one or moreheat sources to a selected section of the formation such that apermeability of at least a portion of the selected section increases togreater than about 100 millidarcy.
 2194. The method of claim 2193,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 2195. The method of claim 2193, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 2196. The method of claim 2193, wherein the one ormore heat sources comprise electrical heaters.
 2197. The method of claim2193, wherein the one or more heat sources comprise surface burners.2198. The method of claim 2193, wherein the one or more heat sourcescomprise flameless distributed combustors.
 2199. The method of claim2193, wherein the one or more heat sources comprise natural distributedcombustors.
 2200. The method of claim 2193, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2201. The method of claim 2193,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2202. The method of claim 2193, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2203. The method of claim 2193, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2204. The method of claim 2193, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2205. The method of claim2193, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons having an APIgravity of at least about 25°.
 2206. The method of claim 2193, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 0.1% byweight to about 15% by weight of the condensable hydrocarbons areolefins.
 2207. The method of claim 2193, further comprising producing amixture from the formation, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 2208. The method of claim 2193, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 2209. The method of claim 2193, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2210. The method of claim 2193, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons issulfur.
 2211. The method of claim 2193, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.2212. The method of claim 2193, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2213. The method ofclaim 2193, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2214. Themethod of claim 2193, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2215. The method of claim2193, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2216. The method of claim 2193, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2217. The method of claim 2193, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2218. The method of claim2193, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2219. The method of claim 2193, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2220. The method of claim 2193, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 2221. The method of claim 2220, furthercomprising producing a mixture from the formation, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2222. The method of claim 2193, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2223. The method of claim 2193, further comprising producing amixture from the formation and controlling formation conditions byrecirculating a portion of hydrogen from the mixture into the formation.2224. The method of claim 2193, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 2225. The method of claim 2193, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 2226. The method of claim2193, further comprising increasing a permeability of a majority of theselected section to greater than about 5 Darcy.
 2227. The method ofclaim 2193, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 2228. The method of claim 2193, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 2229. The methodof claim 2193, further comprising producing a mixture in a productionwell, wherein at least about 7 heat sources are disposed in theformation for each production well.
 2230. The method of claim 2193,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2231.The method of claim 2193, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2232. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation; andallowing the heat to transfer from the one or more heat sources to aselected section of the formation such that a permeability of a majorityof at least a portion of the selected section increases substantiallyuniformly.
 2233. The method of claim 2232, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation.
 2234. Themethod of claim 2232, further comprising maintaining a temperaturewithin the selected section within a pyrolysis temperature range. 2235.The method of claim 2232, wherein the one or more heat sources compriseelectrical heaters.
 2236. The method of claim 2232, wherein the one ormore heat sources comprise surface burners.
 2237. The method of claim2232, wherein the one or more heat sources comprise flamelessdistributed combustors.
 2238. The method of claim 2232, wherein the oneor more heat sources comprise natural distributed combustors.
 2239. Themethod of claim 2232, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.2240. The method of claim 2232, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 2241. The method of claim 2232,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 2242. The methodof claim 2232, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 2243. The method of claim2232, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 2244. The method of claim 2232, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons having an API gravity of at least about 25°.2245. The method of claim 2232, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 2246. The method of claim2232, further comprising producing a mixture from the formation, whereinthe produced mixture comprises non-condensable hydrocarbons, and whereina molar ratio of ethene to ethane in the non-condensable hydrocarbonsranges from about 0.001 to about 0.15.
 2247. The method of claim 2232,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 2248. The method of claim 2232,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 2249. The method of claim 2232,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 2250. The method of claim 2232,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2251. The method of claim 2232, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and wherein greater than about 20%by weight of the condensable hydrocarbons are aromatic compounds. 2252.The method of claim 2232, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 2253. The method of claim 2232, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 0.3% by weight ofthe condensable hydrocarbons are asphaltenes.
 2254. The method of claim2232, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2255. The method of claim 2232, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2256. The method of claim 2232, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2257. The method of claim2232, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2258. The method of claim 2232, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2259. The method of claim 2232, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 2260. The method of claim 2232, furthercomprising producing a mixture from the formation, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2261. The method of claim 2232, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2262. The method of claim 2232, further comprising producing amixture from the formation and controlling formation conditions byrecirculating a portion of hydrogen from the mixture into the formation.2263. The method of claim 2232, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 2264. The method of claim 2232, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 2265. The method of claim2232, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 2266. The method of claim 2232, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 2267. The methodof claim 2232, further comprising producing a mixture in a productionwell, wherein at least about 7 heat sources are disposed in theformation for each production well.
 2268. The method of claim 2232,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2269.The method of claim 2232, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2270. A methodof treating a coal formation in situ, comprising: providing heat fromone or more heat sources to at least a portion of the formation; andallowing the heat to transfer from the one or more heat sources to aselected section of the formation such that a porosity of a majority ofat least a portion of the selected section increases substantiallyuniformly.
 2271. The method of claim 2270, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation.
 2272. Themethod of claim 2270, further comprising maintaining a temperaturewithin the selected section within a pyrolysis temperature range. 2273.The method of claim 2270, wherein the one or more heat sources compriseelectrical heaters.
 2274. The method of claim 2270, wherein the one ormore heat sources comprise surface burners.
 2275. The method of claim2270, wherein the one or more heat sources comprise flamelessdistributed combustors.
 2276. The method of claim 2270, wherein the oneor more heat sources comprise natural distributed combustors.
 2277. Themethod of claim 2270, further comprising controlling a pressure and atemperature within at least a majority of the selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.2278. The method of claim 2270, further comprising controlling the heatsuch that an average heating rate of the selected section is less thanabout 1° C. per day during pyrolysis.
 2279. The method of claim 2270,wherein providing heat from the one or more heat sources to at least theportion of formation comprises: heating a selected volume (V) of thecoal formation from the one or more heat sources, wherein the formationhas an average heat capacity (C_(v)), and wherein the heating pyrolyzesat least some hydrocarbons within the selected volume of the formation;and wherein heating energy/day provided to the volume is equal to orless than Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 2280. The methodof claim 2270, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 2281. The method of claim2270, wherein providing heat from the one or more heat sources comprisesheating the selected section such that a thermal conductivity of atleast a portion of the selected section is greater than about 0.5 W/(m°C.).
 2282. The method of claim 2270, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons having an API gravity of at least about 25°.2283. The method of claim 2270, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 2284. The method of claim2270, further comprising producing a mixture from the formation, whereinthe produced mixture comprises non-condensable hydrocarbons, and whereina molar ratio of ethene to ethane in the non-condensable hydrocarbonsranges from about 0.001 to about 0.15.
 2285. The method of claim 2270,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 2286. The method of claim 2270,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 2287. The method of claim 2270,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 2288. The method of claim 2270,further comprising producing a mixture from the formation, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2289. The method of claim 2270, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and where in greater than about 20%by weight of the condensable hydrocarbons are aromatic compounds. 2290.The method of claim 2270, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 2291. The method of claim 2270, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 0.3% by weight ofthe condensable hydrocarbons are asphaltenes.
 2292. The method of claim2270, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2293. The method of claim 2270, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2294. The method of claim 2270, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2295. The method of claim2270, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2296. The method of claim 2270, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2297. The method of claim 2270, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 2298. The method of claim 2193, furthercomprising producing a mixture from the formation, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2299. The method of claim 2193, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2300. The method of claim 2193, further comprising producing amixture from the formation and controlling formation conditions byrecirculating a portion of hydrogen from the mixture into the formation.2301. The method of claim 2270, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 2302. The method of claim 2270, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 2303. The method of claim2270, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 2304. The method of claim 2270, wherein allowing theheat to transfer comprises substantially uniformly increasing apermeability of a majority of the selected section.
 2305. The method ofclaim 2270, further comprising controlling the heat to yield greaterthan about 60% by weight of condensable hydrocarbons, as measured byFischer Assay.
 2306. The method of claim 2270, further comprisingproducing a mixture in a production well, and wherein at least about 7heat sources are disposed in the formation for each production well.2307. The method of claim 2270, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, and wherein the unit of heat sourcescomprises a triangular pattern.
 2308. The method of claim 2270, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, wherein the unit ofheat sources comprises a triangular pattern, and wherein a plurality ofthe units are repeated over an area of the formation to form arepetitive pattern of units.
 2309. A method of treating a coal formationin situ, comprising: providing heat from one or more heat sources to atleast a portion of the formation; allowing the heat to transfer from theone or more heat sources to a selected section of the formation; andcontrolling the heat to yield at least about 15% by weight of a totalorganic carbon content of at least some of the coal formation intocondensable hydrocarbons.
 2310. The method of claim 2309, wherein theone or more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.2311. The method of claim 2309, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 2312. The method of claim 2309, wherein the one or more heatsources comprise electrical heaters.
 2313. The method of claim 2309,wherein the one or more heat sources comprise surface burners.
 2314. Themethod of claim 2309, wherein the one or more heat sources compriseflameless distributed combustors.
 2315. The method of claim 2309,wherein the one or more heat sources comprise natural distributedcombustors.
 2316. The method of claim 2309, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2317. The method of claim 2309,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2318. The method of claim 2309, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2319. The method of claim 2309, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2320. The method of claim 2309, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2321. The method of claim2309, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons having an APIgravity of at least about 25°.
 2322. The method of claim 2309, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 0.1% byweight to about 15% by weight of the condensable hydrocarbons areolefins.
 2323. The method of claim 2309, further comprising producing amixture from the formation, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 2324. The method of claim 2309, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 2325. The method of claim 2309, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2326. The method of claim 2309, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons issulfur.
 2327. The method of claim 2309, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.2328. The method of claim 2309, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2329. The method ofclaim 2309, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2330. Themethod of claim 2309, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2331. The method of claim2309, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2332. The method of claim 2309, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2333. The method of claim 2309, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2334. The method of claim2309, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2335. The method of claim 2309, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2336. The method of claim 2309, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 2337. The method of claim 2309, furthercomprising producing a mixture from the formation, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2338. The method of claim 2309, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2339. The method of claim 2309, further comprising producing amixture from the formation and controlling formation conditions byrecirculating a portion of hydrogen from the mixture into the formation.2340. The method of claim 2309, further comprising: providing hydrogen(H₂) to the heated section to hydrogenate hydrocarbons within thesection; and heating a portion of the section with heat fromhydrogenation.
 2341. The method of claim 2309, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 2342. The method of claim2309, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 2343. The method of claim 2309, wherein allowing theheat to transfer comprises substantially uniformly increasing apermeability of a majority of the selected section.
 2344. The method ofclaim 2309, wherein the heating is controlled to yield greater thanabout 60% by weight of condensable hydrocarbons, as measured by FischerAssay.
 2345. The method of claim 2309, further comprising producing amixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 2346. The methodof claim 2309, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2347. The method of claim 2309, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2348. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and controlling the heatto yield greater than about 60% by weight of condensable hydrocarbons,as measured by Fischer Assay.
 2349. The method of claim 2348, whereinthe one or more heat sources comprise at least two heat sources, andwherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 2350. The method of claim 2348, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 2351. The method of claim 2348, wherein the one ormore heat sources comprise electrical heaters.
 2352. The method of claim2348, wherein the one or more heat sources comprise surface burners.2353. The method of claim 2348, wherein the one or more heat sourcescomprise flameless distributed combustors.
 2354. The method of claim2348, wherein the one or more heat sources comprise natural distributedcombustors.
 2355. The method of claim 2348, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2356. The method of claim 2348,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2357. The method of claim 2348, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2358. The method of claim 2348, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2359. The method of claim 2348, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2360. The method of claim2348, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons having an APIgravity of at least about 25°.
 2361. The method of claim 2348, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 0.1% byweight to about 15% by weight of the condensable hydrocarbons areolefins.
 2362. The method of claim 2348, further comprising producing amixture from the formation, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 2363. The method of claim 2348, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 2364. The method of claim 2348, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2365. The method of claim 2348, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons issulfur.
 2366. The method of claim 2348, further comprising producing amixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.2367. The method of claim 2348, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2368. The method ofclaim 2348, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises ring aromatics with more than two rings.
 2369. The method ofclaim 2348, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 0.3% by weight of the condensable hydrocarbonsare asphaltenes.
 2370. The method of claim 2348, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons are cycloalkanes.2371. The method of claim 2348, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, wherein the hydrogen is greater than about 10% byvolume of the non-condensable component, and wherein the hydrogen isless than about 80% by volume of the non-condensable component. 2372.The method of claim 2348, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises ammonia, andwherein greater than about 0.05% by weight of the produced mixture isammonia.
 2373. The method of claim 2348, further comprising producing amixture from the formation, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 2374.The method of claim 2348, further comprising controlling a pressurewithin at least a majority of the selected section of the formation,wherein the controlled pressure is at least about 2.0 bar absolute.2375. The method of claim 2348, further comprising controlling formationconditions to produce a mixture from the formation, wherein a partialpressure of H₂ within the mixture is greater than about 0.5 bar. 2376.The method of claim 2348, further comprising producing a mixture fromthe formation, wherein the partial pressure of H₂ within the mixture ismeasured when the mixture is at a production well.
 2377. The method ofclaim 2348, further comprising altering a pressure within the formationto inhibit production of hydrocarbons from the formation having carbonnumbers greater than about
 25. 2378. The method of claim 2348, furthercomprising producing a mixture from the formation and controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2379. The method of claim 2348, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2380. The method of claim 2348, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2381. Themethod of claim 2348, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 2382. The method of claim 2348,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 2383.The method of claim 2348, further comprising producing a mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 2384. The method of claim2348, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2385.The method of claim 2348, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2386. A methodof treating a coal formation in situ, comprising: heating a firstsection of the formation to pyrolyze at least some hydrocarbons in thefirst section and produce a first mixture from the formation, heating asecond section of the formation to pyrolyze at least some hydrocarbonsin the second section and produce a second mixture from the formation;and leaving an unpyrolyzed section between the first section and thesecond section to inhibit subsidence of the formation.
 2387. The methodof claim 2386, further comprising maintaining a temperature within thefirst section or the second section within a pyrolysis temperaturerange.
 2388. The method of claim 2386, wherein heating the first sectionor heating the second section comprises heating with an electricalheater.
 2389. The method of claim 2386, wherein heating the firstsection or heating the second section comprises heating with a surfaceburner.
 2390. The method of claim 2386, wherein heating the firstsection or heating the second section comprises heating with a flamelessdistributed combustor.
 2391. The method of claim 2386, wherein heatingthe first section or heating the second section comprises heating with anatural distributed combustor.
 2392. The method of claim 2386, furthercomprising controlling a pressure and a temperature within at least amajority of the first or second section of the formation, wherein thepressure is controlled as a function of temperature, or the temperatureis controlled as a function of pressure.
 2393. The method of claim 2386,further comprising controlling the heat such that an average heatingrate of the first or second section is less than about 1° C. per dayduring pyrolysis.
 2394. The method of claim 2386, wherein heating thefirst section or heating the second section comprises: heating aselected volume (V) of the coal formation from one or more heat sources,wherein the formation has an average heat capacity (C_(v)), and whereinthe heating pyrolyzes at least some hydrocarbons within the selectedvolume of the formation; and wherein heating energy/day provided to thevolume is equal to or less than Pwr, wherein Pwr is calculated by theequation: Pwr h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, his an average heating rate of the formation, ρ_(B) is formation bulkdensity, and wherein the heating rate is less than about 10° C./day.2395. The method of claim 2386, wherein heating the first section orheating the second section comprises transferring heat substantially byconduction.
 2396. The method of claim 2386, wherein heating the firstsection or heating the second section comprises heating the formationsuch that a thermal conductivity of at least a portion of the first orsecond section, respectively, is greater than about 0.5 W/(m° C.). 2397.The method of claim 2386, wherein the first or second mixture comprisescondensable hydrocarbons having an API gravity of at least about 25°.2398. The method of claim 2386, wherein the first or second mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 2399.The method of claim 2386, wherein the first or second mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 2400. The method of claim 2386, wherein the first or secondmixture comprises condensable hydrocarbons, and wherein less than about1% by weight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 2401. The method of claim 2386, wherein thefirst or second mixture comprises condensable hydrocarbons, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 2402. The method of claim 2386,wherein the first or second mixture comprises condensable hydrocarbons,and wherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 2403. The method ofclaim 2386, wherein the first or second mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 2404. Themethod of claim 2386, wherein the first or second mixture comprisescondensable hydrocarbons, and wherein greater than about 20% by weightof the condensable hydrocarbons are aromatic compounds.
 2405. The methodof claim 2386, wherein the first or second mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 2406. The method of claim 2386, wherein the first or secondmixture comprises condensable hydrocarbons, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 2407.The method of claim 2386, wherein the first or second mixture comprisescondensable hydrocarbons, and wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons are cycloalkanes.
 2408. Themethod of claim 2386, wherein the first or second mixture comprises anon-condensable component, and wherein the non-condensable componentcomprises hydrogen, and wherein the hydrogen is greater than about 10%by volume of the non-condensable component and wherein the hydrogen isless than about 80% by volume of the non-condensable component. 2409.The method of claim 2386, wherein the first or second mixture comprisesammonia, and wherein greater than about 0.05% by weight of the first orsecond mixture is ammonia.
 2410. The method of claim 2386, wherein thefirst or second mixture comprises ammonia, and wherein the ammonia isused to produce fertilizer.
 2411. The method of claim 2386, furthercomprising controlling a pressure within at least a majority of thefirst or second section of the formation, wherein the controlledpressure is at least about 2.0 bar absolute.
 2412. The method of claim2386, further comprising controlling formation conditions to produce thefirst or second mixture, wherein a partial pressure of H₂ within thefirst or second mixture is greater than about 0.5 bar.
 2413. The methodof claim 2386, wherein a partial pressure of H₂ within the first orsecond mixture is measured when the first or second mixture is at aproduction well.
 2414. The method of claim 2386, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2415. The method of claim 2386, further comprising controllingformation conditions by recirculating a portion of hydrogen from thefirst or second mixture into the formation.
 2416. The method of claim2386, further comprising: providing hydrogen (H₂) to the first or secondsection to hydrogenate hydrocarbons within the first or second section,respectively; and heating a portion of the first or second section,respectively, with heat from hydrogenation.
 2417. The method of claim2386, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 2418. The method of claim 2386, wherein heating thefirst section or heating the second section comprises increasing apermeability of a majority of the first or second section, respectively,to greater than about 100 millidarcy.
 2419. The method of claim 2386,wherein heating the first section or heating the second sectioncomprises substantially uniformly increasing a permeability of amajority of the first or second section, respectively.
 2420. The methodof claim 2386, further comprising controlling heating of the first orsecond section to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay, from the first or secondsection, respectively.
 2421. The method of claim 2386, wherein producingthe first or second mixture comprises producing the first or secondmixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 2422. The methodof claim 2386, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2423. The method of claim 2386, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2424. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and producing a mixturefrom the formation through one or more production wells, wherein theheating is controlled such that the mixture can be produced from theformation as a vapor, and wherein at least about 7 heat sources aredisposed in the formation for each production well.
 2425. The method ofclaim 2424, wherein the one or more heat sources comprise at least twoheat sources, and wherein superposition of heat from at least the twoheat sources pyrolyzes at least some hydrocarbons within the selectedsection of the formation.
 2426. The method of claim 2424, furthercomprising maintaining a temperature within the selected section withina pyrolysis temperature range.
 2427. The method of claim 2424, whereinthe one or more heat sources comprise electrical heaters.
 2428. Themethod of claim 2424, wherein the one or more heat sources comprisesurface burners.
 2429. The method of claim 2424, wherein the one or moreheat sources comprise flameless distributed combustors.
 2430. The methodof claim 2424, wherein the one or more heat sources comprise naturaldistributed combustors.
 2431. The method of claim 2424, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2432. The method of claim 2424,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2433. The method of claim 2424, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2434. The method of claim 2424, whereinallowing the heat to transfer comprises transferring heat substantiallyby conduction.
 2435. The method of claim 2424, wherein providing heatfrom the one or more heat sources comprises heating the selected sectionsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2436. The method of claim2424, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2437. The method of claim2424, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2438. The method of claim 2424,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2439. The method ofclaim 2424, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2440.The method of claim 2424, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2441. The method of claim 2424, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2442. The method of claim 2424, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2443. The method of claim 2424, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2444. The method of claim 2424, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2445. The method of claim 2424, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2446. The method of claim 2424, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2447. The method of claim 2424, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2448. The method of claim 2424, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2449. The method of claim2424, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2450. The method of claim 2424,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2451. The method of claim 2424,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2452. The method of claim 2452, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2453. The method of claim 2424, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2454. The method of claim 2424, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2455. The method of claim 2424, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2456. The method of claim 2424, furthercomprising: producing hydrogen and condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2457. Themethod of claim 2424, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the selected section togreater than about 100 millidarcy.
 2458. The method of claim 2424,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the selected section. 2459.The method of claim 2424, wherein the heating is controlled to yieldgreater than about 60% by weight of condensable hydrocarbons, asmeasured by Fischer Assay.
 2460. The method of claim 2424, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, and wherein the unitof heat sources comprises a triangular pattern.
 2461. The method ofclaim 2424, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,wherein the unit of heat sources comprises a triangular pattern, andwherein a plurality of the units are repeated over an area of theformation to form a repetitive pattern of units.
 2462. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation, wherein theone or more heat sources are disposed within one or more first wells;allowing the heat to transfer from the one or more heat sources to aselected section of the formation; and producing a mixture from theformation through one or more second wells, wherein one or more of thefirst or second wells are initially used for a first purpose and arethen used for one or more other purposes.
 2463. The method of claim2462, wherein the first purpose comprises removing water from theformation, and wherein the second purpose comprises providing heat tothe formation.
 2464. The method of claim 2462, wherein the first purposecomprises removing water from the formation, and wherein the secondpurpose comprises producing the mixture.
 2465. The method of claim 2462,wherein the first purpose comprises heating, and wherein the secondpurpose comprises removing water from the formation.
 2466. The method ofclaim 2462, wherein the first purpose comprises producing the mixture,and wherein the second purpose comprises removing water from theformation.
 2467. The method of claim 2462, wherein the one or more heatsources comprise electrical heaters.
 2468. The method of claim 2462,wherein the one or more heat sources comprise surface burners.
 2469. Themethod of claim 2462, wherein the one or more heat sources compriseflameless distributed combustors.
 2470. The method of claim 2462,wherein the one or more heat sources comprise natural distributedcombustors.
 2471. The method of claim 2462, farther comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2472. The method of claim 2462,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1.0° C. per day duringpyrolysis.
 2473. The method of claim 2462, wherein providing heat fromthe one or more heat sources to at least the portion of the formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2474. The method of claim 2462, whereinproviding heat from the one or more heat sources comprises heating theselected section such that a thermal conductivity of at least a portionof the selected section is greater than about 0.5 W/(m° C.).
 2475. Themethod of claim 2462, wherein the produced mixture comprises condensablehydrocarbons having an API gravity of at least about 25°.
 2476. Themethod of claim 2462, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 2477. The method of claim2462, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.2478. The method of claim 2462, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 2479. The method of claim 2462, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is oxygen.
 2480. The method of claim 2462, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 2481. The method of claim 2462,wherein the produced mixture comprises condensable hydrocarbons, whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons comprise oxygen containing compounds, and wherein theoxygen containing compounds comprise phenols.
 2482. The method of claim2462, wherein the produced mixture comprises condensable hydrocarbons,and wherein greater than about 20% by weight of the condensablehydrocarbons are aromatic compounds.
 2483. The method of claim 2462,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2484. Themethod of claim 2462, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2485. The method of claim2462, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2486. The method of claim 2462, whereinthe produced mixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2487. The method of claim 2462, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2488. The method of claim2462, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2489. The method of claim 2462,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2490. The method of claim 2462,further comprising controlling formation conditions to produce a mixtureof condensable hydrocarbons and H₂, wherein a partial pressure of H₂within the mixture is greater than about 0.5 bar.
 2491. The method ofclaim 2490, wherein the partial pressure of H₂ is measured when themixture is at a production well.
 2492. The method of claim 2462, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 2493. The method of claim 2462, furthercomprising controlling formation conditions, wherein controllingformation conditions comprises recirculating a portion of hydrogen fromthe mixture into the formation.
 2494. The method of claim 2462, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2495. The method of claim 2462, whereinthe produced mixture comprises hydrogen and condensable hydrocarbons,the method further comprising hydrogenating a portion of the producedcondensable hydrocarbons with at least a portion of the producedhydrogen.
 2496. The method of claim 2462, wherein allowing the heat totransfer comprises increasing a permeability of a majority of theselected section to greater than about 100 millidarcy.
 2497. The methodof claim 2462, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 2498. The method of claim 2462, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 2499. The methodof claim 2462, wherein producing the mixture comprises producing themixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 2500. The methodof claim 2462, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2501. The method of claim 2462, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2502. A method for forming heater wells in a coal formation, comprising:forming a first wellbore in the formation; forming a second wellbore inthe formation using magnetic tracking such that the second wellbore isarranged substantially parallel to the first wellbore; and providing atleast one heating mechanism within the first wellbore and at least oneheating mechanism within the second wellbore such that the heatingmechanisms can provide heat to at least a portion of the formation.2503. The method of claim 2502, wherein superposition of heat from theat least one heating mechanism within the first wellbore and the atleast one heating mechanism within the second wellbore pyrolyzes atleast some hydrocarbons within a selected section of the formation.2504. The method of claim 2502, further comprising maintaining atemperature within a selected section within a pyrolysis temperaturerange.
 2505. The method of claim 2502, wherein the heating mechanismscomprise electrical heaters.
 2506. The method of claim 2502, wherein theheating mechanisms comprise surface burners.
 2507. The method of claim2502, wherein the heating mechanisms comprise flameless distributedcombustors.
 2508. The method of claim 2502, wherein the heatingmechanisms comprise natural distributed combustors.
 2509. The method ofclaim 2502, further comprising controlling a pressure and a temperaturewithin at least a majority of a selected section of the formation,wherein the pressure is controlled as a function of temperature, or thetemperature is controlled as a function of pressure.
 2510. The method ofclaim 2502, further comprising controlling the heat from the heatingmechanisms such that heat transferred from the heating mechanisms to atleast the portion of the hydrocarbons is less than about 1° C. per dayduring pyrolysis.
 2511. The method of claim 2502, further comprising:heating a selected volume (V) of the coal formation from the heatingmechanisms, wherein the formation has an average heat capacity (C_(v)),and wherein the heating pyrolyzes at least some hydrocarbons within theselected volume of the formation; and wherein heating energy/dayprovided to the volume is equal to or less than Pwr, wherein Pwr iscalculated by the equation: Pwr =h*V*C_(v)*ρ_(B) wherein Pwr is theheating energy/day, h is an average heating rate of the formation, ρ_(B)is formation bulk density, and wherein the heating rate is less thanabout 10° C./day.
 2512. The method of claim 2502, further comprisingallowing the heat to transfer from the heating mechanisms to at leastthe portion of the formation substantially by conduction.
 2513. Themethod of claim 2502, further comprising providing heat from the heatingmechanisms to at least the portion of the formation such that a thermalconductivity of at least the portion of the formation is greater thanabout 0.5 W/(m° C.).
 2514. The method of claim 2502, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 2515. The method of claim 2502, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein about 0.1% by weight to about 15%by weight of the condensable hydrocarbons are olefins.
 2516. The methodof claim 2502, further comprising producing a mixture from theformation, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.2517. The method of claim 2502, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2518.The method of claim 2502, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 2519. Themethod of claim 2502, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 2520. Themethod of claim 2502, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 2521. Themethod of claim 2502, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2522. The method ofclaim 2502, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2523. Themethod of claim 2502, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2524. The method of claim2502, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2525. The method of claim 2502, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2526. The method of claim 2502, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2527. The method of claim2502, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2528. The method of claim 2502, furthercomprising controlling a pressure within at least a majority of aselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2529. The method of claim 2528, whereinthe partial pressure of H₂ within the mixture is greater than about 0.5bar.
 2530. The method of claim 2502, further comprising producing amixture from the formation, wherein the partial pressure of H₂ withinthe mixture is measured when the mixture is at a production well. 2531.The method of claim 2502, further comprising altering a pressure withinthe formation to inhibit production of hydrocarbons from the formationhaving carbon numbers greater than about
 25. 2532. The method of claim2502, further comprising producing a mixture from the formation andcontrolling formation conditions by recirculating a portion of hydrogenfrom the mixture into the formation.
 2533. The method of claim 2502,further comprising: providing hydrogen (H₂) to the portion tohydrogenate hydrocarbons within the formation; and heating a portion ofthe formation with heat from hydrogenation.
 2534. The method of claim2502, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 2535. The method of claim 2502, further comprisingallowing heat to transfer from the heating mechanisms to a selectedsection of the formation to pyrolyze at least some hydrocarbons withinthe selected section such that a permeability of a majority of aselected section of the formation increases to greater than about 100millidarcy.
 2536. The method of claim 2502, further comprising allowingheat to transfer from the heating mechanisms to a selected section ofthe formation to pyrolyze at least some hydrocarbons within the selectedsection such that a permeability of a majority of the selected sectionincreases substantially uniformly.
 2537. The method of claim 2502,further comprising controlling the heat to yield greater than about 60%by weight of condensable hydrocarbons, as measured by Fischer Assay.2538. The method of claim 2502, further comprising producing a mixturein a production well, and wherein at least about 7 heat sources aredisposed in the formation for each production well.
 2539. The method ofclaim 2502, further comprising forming a production well in theformation using magnetic tracking such that the production well issubstantially parallel to the first wellbore and coupling a wellhead tothe third wellbore.
 2540. The method of claim 2502, further comprisingproviding heat from three or more heat sources to at least a portion ofthe formation, wherein three or more of the heat sources are located inthe formation in a unit of heat sources, and wherein the unit of heatsources comprises a triangular pattern.
 2541. The method of claim 2502,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, whereinthe unit of heat sources comprises a triangular pattern, and wherein aplurality of the units are repeated over an area of the formation toform a repetitive pattern of units.
 2542. A method for installing aheater well into a coal formation, comprising: forming a bore in theground using a steerable motor and an accelerometer; and providing aheating mechanism within the bore such that the heating mechanism cantransfer heat to at least a portion of the formation.
 2543. The methodof claim 2542, further comprising installing at least two heater wells,and wherein superposition of heat from at least the two heater wellspyrolyzes at least some hydrocarbons within a selected section of theformation.
 2544. The method of claim 2542, further comprisingmaintaining a temperature within a selected section within a pyrolysistemperature range.
 2545. The method of claim 2542, wherein the heatingmechanism comprises an electrical heater.
 2546. The method of claim2542, wherein the heating mechanism comprises a surface burner. 2547.The method of claim 2542, wherein the heating mechanism comprises aflameless distributed combustor.
 2548. The method of claim 2542, whereinthe heating mechanism comprises a natural distributed combustor. 2549.The method of claim 2542, further comprising controlling a pressure anda temperature within at least a majority of a selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.2550. The method of claim 2542, further comprising controlling the heatfrom the heating mechanism such that heat transferred from the heatingmechanism to at least the portion of the formation is less than about 1°C. per day during pyrolysis.
 2551. The method of claim 2542, furthercomprising: heating a selected volume (V) of the coal formation from theheating mechanism, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 2552. The method of claim 2542, furthercomprising allowing the heat to transfer from the heating mechanism toat least the portion of the formation substantially by conduction. 2553.The method of claim 2542, further comprising providing heat from theheating mechanism to at least the portion of the formation such that athermal conductivity of at least the portion of the formation is greaterthan about 0.5 W/(m° C.).
 2554. The method of claim 2542, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises condensable hydrocarbons having an API gravity of atleast about 25°.
 2555. The method of claim 2542, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 2556.The method of claim 2542, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.2557. The method of claim 2542, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2558.The method of claim 2542, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 2559. Themethod of claim 2542, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 2560. Themethod of claim 2542, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 2561. Themethod of claim 2542, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2562. The method ofclaim 2542, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2563. Themethod of claim 2542, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2564. The method of claim2542, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2565. The method of claim 2542, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2566. The method of claim 2542, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2567. The method of claim2542, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2568. The method of claim 2542, furthercomprising controlling a pressure within at least a majority of aselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2569. The method of claim 2542, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 2570. The method of claim 2569, wherein thepartial pressure of H₂ within the mixture is measured when the mixtureis at a production well.
 2571. The method of claim 2542, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 2572. The method of claim 2542, furthercomprising producing a mixture from the formation and controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2573. The method of claim 2542, furthercomprising: providing hydrogen (H₂) to the at least the heated portionto hydrogenate hydrocarbons within the formation; and heating a portionof the formation with heat from hydrogenation.
 2574. The method of claim2542, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 2575. The method of claim 2542, further comprisingallowing heat to transfer from the heating mechanism to a selectedsection of the formation to pyrolyze at least some hydrocarbons withinthe selected section such that a permeability of a majority of aselected section of the formation increases to greater than about 100millidarcy.
 2576. The method of claim 2542, further comprising allowingheat to transfer from the heating mechanism to a selected section of theformation to pyrolyze at least some hydrocarbons within the selectedsection such that a permeability of a majority of the selected sectionincreases substantially uniformly.
 2577. The method of claim 2542,further comprising controlling the heat to yield greater than about 60%by weight of condensable hydrocarbons, as measured by Fischer Assay.2578. The method of claim 2542, further comprising producing a mixturein a production well, and wherein at least about 7 heating mechanismsare disposed in the formation for each production well.
 2579. The methodof claim 2542, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2580. The method of claim 2542, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2581. A method for installing of wells in a coal formation, comprising:forming a wellbore in the formation by geosteered drilling; andproviding a heating mechanism within the wellbore such that the heatingmechanism can transfer heat to at least a portion of the formation.2582. The method of claim 2581, further comprising maintaining atemperature within a selected section within a pyrolysis temperaturerange.
 2583. The method of claim 2581, wherein the heating mechanismcomprises an electrical heater.
 2584. The method of claim 2581, whereinthe heating mechanism comprises a surface burner.
 2585. The method ofclaim 2581, wherein the heating mechanism comprises a flamelessdistributed combustor.
 2586. The method of claim 2581, wherein theheating mechanism comprises a natural distributed combustor.
 2587. Themethod of claim 2581, further comprising controlling a pressure and atemperature within at least a majority of a selected section of theformation, wherein the pressure is controlled as a function oftemperature, or the temperature is controlled as a function of pressure.2588. The method of claim 2581, further comprising controlling the heatfrom the heating mechanism such that heat transferred from the heatingmechanism to at least the portion of the formation is less than about 1°C. per day during pyrolysis.
 2589. The method of claim 2581, furthercomprising: heating a selected volume (V) of the coal formation from theheating mechanism, wherein the formation has an average heat capacity(C_(v)), and wherein the heating pyrolyzes at least some hydrocarbonswithin the selected volume of the formation; and wherein heatingenergy/day provided to the volume is equal to or less than Pwr, whereinPwr is calculated by the equation: Pwr h*V*C_(v)*ρ_(B) wherein Pwr isthe heating energy/day, h is an average heating rate of the formation,ρ_(B) is formation bulk density, and wherein the heating rate is lessthan about 10° C./day.
 2590. The method of claim 2581, furthercomprising allowing the heat to transfer from the heating mechanism toat least the portion of the formation substantially by conduction. 2591.The method of claim 2581, further comprising providing heat from theheating mechanism to at least the portion of the formation such that athermal conductivity of at least the portion of the formation is greaterthan about 0.5 W/(m° C.).
 2592. The method of claim 2581, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises condensable hydrocarbons having an API gravity of atleast about 25°.
 2593. The method of claim 2581, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 2594.The method of claim 2581, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.2595. The method of claim 2581, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2596.The method of claim 2581, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 2597. Themethod of claim 2581, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 2598. Themethod of claim 2581, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 2599. Themethod of claim 2581, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2600. The method ofclaim 2581, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2601. Themethod of claim 2581, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2602. The method of claim2581, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2603. The method of claim 2581, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2604. The method of claim 2581, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2605. The method of claim2581, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2606. The method of claim 2581, furthercomprising controlling a pressure within at least a majority of aselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 2607. The method of claim 2581, furthercomprising controlling formation conditions to produce a mixture fromthe formation, wherein a partial pressure of H₂ within the mixture isgreater than about 0.5 bar.
 2608. The method of claim 2607, wherein thepartial pressure of H₂ within the mixture is measured when the mixtureis at a production well.
 2609. The method of claim 2581, furthercomprising altering a pressure within the formation to inhibitproduction of hydrocarbons from the formation having carbon numbersgreater than about
 25. 2610. The method of claim 2581, furthercomprising producing a mixture from the formation and controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2611. The method of claim 2581, furthercomprising: providing hydrogen (H₂) to at least the heated portion tohydrogenate hydrocarbons within the formation; and heating a portion ofthe formation with heat from hydrogenation.
 2612. The method of claim2581, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 2613. The method of claim 2581, further comprisingallowing heat to transfer from the heating mechanism to a selectedsection of the formation to pyrolyze at least some hydrocarbons withinthe selected section such that a permeability of a majority of aselected section of the formation increases to greater than about 100millidarcy.
 2614. The method of claim 2581, further comprising allowingheat to transfer from the heating mechanism to a selected section of theformation to pyrolyze at least some hydrocarbons within the selectedsection such that a permeability of a majority of the selected sectionincreases substantially uniformly.
 2615. The method of claim 2581,further comprising controlling the heat to yield greater than about 60%by weight of condensable hydrocarbons, as measured by Fischer Assay.2616. The method of claim 2581, further comprising producing a mixturein a production well, and wherein at least about 7 heat sources aredisposed in the formation for each production well.
 2617. The method ofclaim 2581, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2618. The method of claim 2581, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2619. A method of treating a coal formation in situ, comprising: heatinga selected section of the formation with a heating element placed withina wellbore, wherein at least one end of the heating element is free tomove axially within the wellbore to allow for thermal expansion of theheating element.
 2620. The method of claim 2619, further comprising atleast two heating elements within at least two wellbores, and whereinsuperposition of heat from at least the two heating elements pyrolyzesat least some hydrocarbons within a selected section of the formation.2621. The method of claim 2619, further comprising maintaining atemperature within the selected section within a pyrolysis temperaturerange.
 2622. The method of claim 2619, wherein the heating elementcomprises a pipe-in-pipe heater.
 2623. The method of claim 2619, whereinthe heating element comprises a flameless distributed combustor. 2624.The method of claim 2619, wherein the heating element comprises amineral insulated cable coupled to a support, and wherein the support isfree to move within the wellbore.
 2625. The method of claim 2619,wherein the heating element comprises a mineral insulated cablesuspended from a wellhead.
 2626. The method of claim 2619, furthercomprising controlling a pressure and a temperature within at least amajority of a heated section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2627. The method of claim 2619,further comprising controlling the heat such that an average heatingrate of the heated section is less than about 1° C. per day duringpyrolysis.
 2628. The method of claim 2619, wherein heating the sectionof the formation further comprises: heating a selected volume (V) of thecoal formation from the heating element, wherein the formation has anaverage heat capacity (C_(v)), and wherein the heating pyrolyzes atleast some hydrocarbons within the selected volume of the formation; andwherein heating energy/day provided to the volume is equal to or lessthan Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 2629. The methodof claim 2619, wherein heating the section of the formation comprisestransferring heat substantially by conduction.
 2630. The method of claim2619, further comprising heating the selected section of the formationsuch that a thermal conductivity of the selected section is greater thanabout 0.5 W/(m° C.).
 2631. The method of claim 2619, further comprisingproducing a mixture from the formation, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 2632. The method of claim 2619, further comprising producinga mixture from the formation, wherein the produced mixture comprisescondensable hydrocarbons, and wherein about 0.1% by weight to about 15%by weight of the condensable hydrocarbons are olefins.
 2633. The methodof claim 2619, further comprising producing a mixture from theformation, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.2634. The method of claim 2619, further comprising producing a mixturefrom the formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2635.The method of claim 2619, further comprising producing a mixture fromthe formation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is oxygen.
 2636. Themethod of claim 2619, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is sulfur.
 2637. Themethod of claim 2619, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 2638. Themethod of claim 2619, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 2639. The method ofclaim 2619, further comprising producing a mixture from the formation,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2640. Themethod of claim 2619, further comprising producing a mixture from theformation, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2641. The method of claim2619, further comprising producing a mixture from the formation, whereinthe produced mixture comprises condensable hydrocarbons, and whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2642. The method of claim 2619, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2643. The method of claim 2619, furthercomprising producing a mixture from the formation, wherein the producedmixture comprises ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 2644. The method of claim2619, further comprising producing a mixture from the formation, whereinthe produced mixture comprises ammonia, and wherein the ammonia is usedto produce fertilizer.
 2645. The method of claim 2619, furthercomprising controlling a pressure within the selected section of theformation, wherein the controlled pressure is at least about 2.0 barabsolute.
 2646. The method of claim 2619, further comprising controllingformation conditions to produce a mixture from the formation, wherein apartial pressure of H₂ within the mixture is greater than about 0.5 bar.2647. The method of claim 2647, wherein the partial pressure of H₂within the mixture is measured when the mixture is at a production well.2648. The method of claim 2619, further comprising altering a pressurewithin the formation to inhibit production of hydrocarbons from theformation having carbon numbers greater than about
 25. 2649. The methodof claim 2619, further comprising producing a mixture from the formationand controlling formation conditions by recirculating a portion ofhydrogen from the mixture into the formation.
 2650. The method of claim2619, further comprising: providing hydrogen (H₂) to the heated sectionto hydrogenate hydrocarbons within the heated section; and heating aportion of the section with heat from hydrogenation.
 2651. The method ofclaim 2619, further comprising: producing hydrogen and condensablehydrocarbons from the formation; and hydrogenating a portion of theproduced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 2652. The method of claim 2619, wherein heatingcomprises increasing a permeability of a majority of the heated sectionto greater than about 100 millidarcy.
 2653. The method of claim 2619,wherein heating comprises substantially uniformly increasing apermeability of a majority of the heated section.
 2654. The method ofclaim 2619, wherein the heating is controlled to yield greater thanabout 60% by weight of condensable hydrocarbons, as measured by FischerAssay.
 2655. The method of claim 2619, further comprising producing amixture in a production well, and wherein at least about 7 heat sourcesare disposed in the formation for each production well.
 2656. The methodof claim 2619, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.2657. The method of claim 2619, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, wherein the unit of heat sources comprises atriangular pattern, and wherein a plurality of the units are repeatedover an area of the formation to form a repetitive pattern of units.2658. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation; and producing a mixturefrom the formation through a production well, wherein the productionwell is located such that a majority of the mixture produced from theformation comprises non-condensable hydrocarbons and a non-condensablecomponent comprising hydrogen.
 2659. The method of claim 2658, whereinthe one or more heat sources comprise at least two heat sources, andwherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 2660. The method of claim 2658, further comprisingmaintaining a temperature within the selected section within a pyrolysistemperature range.
 2661. The method of claim 2658, wherein theproduction well is less than approximately 6 m from a heat source of theone or more heat sources.
 2662. The method of claim 2658, wherein theproduction well is less than approximately 3 m from a heat source of theone or more heat sources.
 2663. The method of claim 2658, wherein theproduction well is less than approximately 1.5 m from a heat source ofthe one or more heat sources.
 2664. The method of claim 2658, wherein anadditional heat source is positioned within a wellbore of the productionwell.
 2665. The method of claim 2658, wherein the one or more heatsources comprise electrical heaters.
 2666. The method of claim 2658,wherein the one or more heat sources comprise surface burners.
 2667. Themethod of claim 2658, wherein the one or more heat sources compriseflameless distributed combustors.
 2668. The method of claim 2658,wherein the one or more heat sources comprise natural distributedcombustors.
 2669. The method of claim 2658, further comprisingcontrolling a pressure and a temperature within at least a majority ofthe selected section of the formation, wherein the pressure iscontrolled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 2670. The method of claim 2658,further comprising controlling the heat such that an average heatingrate of the selected section is less than about 1° C. per day duringpyrolysis.
 2671. The method of claim 2658, wherein providing heat fromthe one or more heat sources to at least the portion of formationcomprises: heating a selected volume (V) of the coal formation from theone or more heat sources, wherein the formation has an average heatcapacity (C_(v)), and wherein the heating pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C P*ρ _(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 2672. The method of claim 2658, whereinallowing the heat to transfer from the one or more heat sources to theselected section comprises transferring heat substantially byconduction.
 2673. The method of claim 2658, wherein providing heat fromthe one or more heat sources comprises heating the selected section suchthat a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2674. The method of claim2658, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2675. The method of claim2658, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2676. The method of claim 2658,wherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2677. The method ofclaim 2658, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2678.The method of claim 2658, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2679. The method of claim 2658, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2680. The method of claim 2658, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2681. The method of claim 2658, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2682. The method of claim 2658, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2683. The method of claim 2658, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2684. The method of claim 2658, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2685. The method of claim 2658, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2686. The method of claim 2658, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2687. The method of claim2658, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2688. The method of claim 2658,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2689. The method of claim 2658,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2690. The method of claim 2689, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2691. The method of claim 2658, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2692. The method of claim 2658, further comprising controllingformation conditions by recirculating a portion of the hydrogen from themixture into the formation.
 2693. The method of claim 2658, furthercomprising: providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 2694. The method of claim 2658, furthercomprising: producing condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 2695. The method of claim2658, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 2696. The method of claim 2658, wherein allowing theheat to transfer comprises substantially uniformly increasing apermeability of a majority of the selected section.
 2697. The method ofclaim 2658, further comprising controlling the heat to yield greaterthan about 60% by weight of condensable hydrocarbons, as measured byFischer Assay.
 2698. The method of claim 2658, wherein producing themixture comprises producing the mixture in a production well, andwherein at least about 7 heat sources are disposed in the formation foreach production well.
 2699. The method of claim 2658, further comprisingproviding heat from three or more heat sources to at least a portion ofthe formation, wherein three or more of the heat sources are located inthe formation in a unit of heat sources, and wherein the unit of heatsources comprises a triangular pattern.
 2700. The method of claim 2658,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, whereinthe unit of heat sources comprises a triangular pattern, and wherein aplurality of the units are repeated over an area of the formation toform a repetitive pattern of units.
 2701. A method of treating a coalformation in situ, comprising: providing heat to at least a portion ofthe formation from one or more first heat sources placed within apattern in the formation; allowing the heat to transfer from the one ormore first heat sources to a first section of the formation; heating asecond section of the formation with at least one second heat source,wherein the second section is located within the first section, andwherein at least the one second heat source is configured to raise anaverage temperature of a portion of the second section to a highertemperature than an average temperature of the first section; andproducing a mixture from the formation through a production wellpositioned within the second section, wherein a majority of the producedmixture comprises non-condensable hydrocarbons and a non-condensablecomponent comprising H₂ components.
 2702. The method of claim 2701,wherein the one or more first heat sources comprise at least two heatsources, and wherein superposition of heat from at least the two heatsources pyrolyzes at least some hydrocarbons within the first section ofthe formation.
 2703. The method of claim 2701, further comprisingmaintaining a temperature within the first section within a pyrolysistemperature range.
 2704. The method of claim 2701, wherein at least theone heat source comprises a heater element positioned within theproduction well.
 2705. The method of claim 2701, wherein at least theone second heat source comprises an electrical heater.
 2706. The methodof claim 2701, wherein at least the one second heat source comprises asurface burner.
 2707. The method of claim 2701, wherein at least the onesecond heat source comprises a flameless distributed combustor. 2708.The method of claim 2701, wherein at least the one second heat sourcecomprises a natural distributed combustor.
 2709. The method of claim2701, further comprising controlling a pressure and a temperature withinat least a majority of the first or the second section of the formation,wherein the pressure is controlled as a function of temperature, or thetemperature is controlled as a function of pressure.
 2710. The method ofclaim 2701, further comprising controlling the heat such that an averageheating rate of the first section is less than about 1° C. per dayduring pyrolysis.
 2711. The method of claim 2701, wherein providing heatto the formation further comprises: heating a selected volume (V) of thefrom the one or more first heat sources, wherein the formation has anaverage heat capacity (C_(v)), and wherein the heating pyrolyzes atleast some hydrocarbons within the selected volume of the formation; andwherein heating energy/day provided to the volume is equal to or lessthan Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 2712. The methodof claim 2701, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 2713. The method of claim2701, wherein providing heat from the one or more first heat sourcescomprises heating the first section such that a thermal conductivity ofat least a portion of the first section is greater than about 0.5 W/(m°C.).
 2714. The method of claim 2701, wherein the produced mixturecomprises condensable hydrocarbons having an API gravity of at leastabout 25°.
 2715. The method of claim 2701, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 2716.The method of claim 2701, wherein a molar ratio of ethene to ethane inthe non-condensable hydrocarbons ranges from about 0.001 to about 0.15.2717. The method of claim 2701, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 2718. The method of claim 2701, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is oxygen.
 2719. The method of claim 2701, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 2720. The method of claim 2701,wherein the produced mixture comprises condensable hydrocarbons, whereinabout 5% by weight to about 30% by weight of the condensablehydrocarbons comprise oxygen containing compounds, and wherein theoxygen containing compounds comprise phenols.
 2721. The method of claim2701, wherein the produced mixture comprises condensable hydrocarbons,and wherein greater than about 20% by weight of the condensablehydrocarbons are aromatic compounds.
 2722. The method of claim 2701,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 2723. Themethod of claim 2701, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 2724. The method of claim2701, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 2725. The method of claim 2701, whereinthe produced mixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2726. The method of claim 2701, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2727. The method of claim2701, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2728. The method of claim 2701,further comprising controlling a pressure within at least a majority ofthe first or the second section of the formation, wherein the controlledpressure is at least about 2.0 bar absolute.
 2729. The method of claim2701, further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2730. The method of claim 2729, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2731. The method of claim 2701, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2732. The method of claim 2701, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2733. The method of claim 2701, furthercomprising: providing hydrogen (H₂) to the first or second section tohydrogenate hydrocarbons within the first or second section,respectively; and heating a portion of the first or second section,respectively, with heat from hydrogenation.
 2734. The method of claim2701, further comprising: producing condensable hydrocarbons from theformation; and hydrogenating a portion of the produced condensablehydrocarbons with at least a portion of the produced hydrogen.
 2735. Themethod of claim 2701, wherein allowing the heat to transfer comprisesincreasing a permeability of a majority of the first or second sectionto greater than about 100 millidarcy.
 2736. The method of claim 2701,wherein allowing the heat to transfer comprises substantially uniformlyincreasing a permeability of a majority of the first or second section.2737. The method of claim 2701, wherein heating the first or the secondsection is controlled to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 2738. The methodof claim 2701, wherein at least about 7 heat sources are disposed in theformation for each production well.
 2739. The method of claim 2701,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2740.The method of claim 2701, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2741. A methodof treating a coal formation in situ, comprising: providing heat intothe formation from a plurality of heat sources placed in a patternwithin the formation, wherein a spacing between heat sources is greaterthan about 6 m; allowing the heat to transfer from the plurality of heatsources to a selected section of the formation; producing a mixture fromthe formation from a plurality of production wells, wherein theplurality of production wells are positioned within the pattern, andwherein a spacing between production wells is greater than about 12 m.2742. The method of claim 2741, wherein superposition of heat from theplurality of heat sources pyrolyzes at least some hydrocarbons withinthe selected section of the formation.
 2743. The method of claim 2741,further comprising maintaining a temperature within the selected sectionwithin a pyrolysis temperature range.
 2744. The method of claim 2741,wherein the plurality of heat sources comprises electrical heaters.2745. The method of claim 2741, wherein the plurality of heat sourcescomprises surface burners.
 2746. The method of claim 2741, wherein theplurality of heat sources comprises flameless distributed combustors.2747. The method of claim 2741, wherein the plurality of heat sourcescomprises natural distributed combustors.
 2748. The method of claim2741, further comprising controlling a pressure and a temperature withinat least a majority of the selected section of the formation, whereinthe pressure is controlled as a function of temperature, or thetemperature is controlled as a function of pressure.
 2749. The method ofclaim 2741, further comprising controlling the heat such that an averageheating rate of the selected section is less than about 1° C. per dayduring pyrolysis.
 2750. The method of claim 2741, wherein providing heatfrom the plurality of heat comprises: heating a selected volume (V) ofthe coal formation from the plurality of heat sources, wherein theformation has an average heat capacity (C_(v)), and wherein the heatingpyrolyzes at least some hydrocarbons within the selected volume of theformation; and wherein heating energy/day provided to the volume isequal to or less than Pwr, wherein Pwr is calculated by the equation:Pwr=h*V*C,*ρ _(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 2751. The methodof claim 2741, wherein allowing the heat to transfer comprisestransferring heat substantially by conduction.
 2752. The method of claim2741, wherein providing heat comprises heating the selected formationsuch that a thermal conductivity of at least a portion of the selectedsection is greater than about 0.5 W/(m° C.).
 2753. The method of claim2741, wherein the produced mixture comprises condensable hydrocarbonshaving an API gravity of at least about 25°.
 2754. The method of claim2741, wherein the produced mixture comprises condensable hydrocarbons,and wherein about 0.1% by weight to about 15% by weight of thecondensable hydrocarbons are olefins.
 2755. The method of claim 2741,wherein the produced mixture comprises non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 2756. The method ofclaim 2741, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 2757.The method of claim 2741, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 2758. The method of claim 2741, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 2759. The method of claim 2741, wherein theproduced mixture comprises condensable hydrocarbons, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 2760. The method of claim 2741, wherein the producedmixture comprises condensable hydrocarbons, and wherein greater thanabout 20% by weight of the condensable hydrocarbons are aromaticcompounds.
 2761. The method of claim 2741, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 2762. The method of claim 2741, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 0.3% by weight of the condensable hydrocarbons areasphaltenes.
 2763. The method of claim 2741, wherein the producedmixture comprises condensable hydrocarbons, and wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 2764. The method of claim 2741, wherein the producedmixture comprises a non-condensable component, wherein thenon-condensable component comprises hydrogen, wherein the hydrogen isgreater than about 10% by volume of the non-condensable component, andwherein the hydrogen is less than about 80% by volume of thenon-condensable component.
 2765. The method of claim 2741, wherein theproduced mixture comprises ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 2766. The method of claim2741, wherein the produced mixture comprises ammonia, and wherein theammonia is used to produce fertilizer.
 2767. The method of claim 2741,further comprising controlling a pressure within at least a majority ofthe selected section of the formation, wherein the controlled pressureis at least about 2.0 bar absolute.
 2768. The method of claim 2741,further comprising controlling formation conditions to produce themixture, wherein a partial pressure of H₂ within the mixture is greaterthan about 0.5 bar.
 2769. The method of claim 2768, wherein the partialpressure of H₂ within the mixture is measured when the mixture is at aproduction well.
 2770. The method of claim 2741, further comprisingaltering a pressure within the formation to inhibit production ofhydrocarbons from the formation having carbon numbers greater than about25.
 2771. The method of claim 2741, further comprising controllingformation conditions by recirculating a portion of hydrogen from themixture into the formation.
 2772. The method of claim 2741, furthercomprising: providing hydrogen (H₂) to the selected section tohydrogenate hydrocarbons within the selected section; and heating aportion of the selected section with heat from hydrogenation.
 2773. Themethod of claim 2741, further comprising: producing hydrogen andcondensable hydrocarbons from the formation; and hydrogenating a portionof the produced condensable hydrocarbons with at least a portion of theproduced hydrogen.
 2774. The method of claim 2741, wherein allowing theheat to transfer comprises increasing a permeability of a majority ofthe selected section to greater than about 100 millidarcy.
 2775. Themethod of claim 2741, wherein allowing the heat to transfer comprisessubstantially uniformly increasing a permeability of a majority of theselected section.
 2776. The method of claim 2741, further comprisingcontrolling the heat to yield greater than about 60% by weight ofcondensable hydrocarbons, as measured by Fischer Assay.
 2777. The methodof claim 2741, wherein at least about 7 heat sources are disposed in theformation for each production well.
 2778. The method of claim 2741,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 2779.The method of claim 2741, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 2780. A systemconfigured to heat a coal formation, comprising: a heater disposed in anopening in the formation, wherein the heater is configured to provideheat to at least a portion of the formation during use; an oxidizingfluid source; a conduit disposed in the opening, wherein the conduit isconfigured to provide an oxidizing fluid from the oxidizing fluid sourceto a reaction zone in the formation during use, and wherein theoxidizing fluid is selected to oxidize at least some hydrocarbons at thereaction zone during use such that heat is generated at the reactionzone; and wherein the system is configured to allow heat to transfersubstantially by conduction from the reaction zone to a pyrolysis zoneof the formation during use.
 2781. The system of claim 2780, wherein theoxidizing fluid is configured to generate heat in the reaction zone suchthat the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 2782. The system of claim 2780, wherein theconduit comprises orifices, and wherein the orifices are configured toprovide the oxidizing fluid into the opening.
 2783. The system of claim2780, wherein the conduit comprises critical flow orifices, and whereinthe critical flow orifices are configured to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 2784. The system of claim 2780, wherein the conduit isfurther configured to be cooled with the oxidizing fluid such that theconduit is not substantially heated by oxidation.
 2785. The system ofclaim 2780, wherein the conduit is further configured to remove anoxidation product.
 2786. The system of claim 2780, wherein the conduitis further configured to remove an oxidation product such that theoxidation product transfers substantial heat to the oxidizing fluid.2787. The system of claim 2780, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein a flow rate ofthe oxidizing fluid in the conduit is approximately equal to a flow rateof the oxidation product in the conduit.
 2788. The system of claim 2780,wherein the conduit is further configured to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.2789. The system of claim 2780, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 2790. The system of claim 2780,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 2791. The system ofclaim 2780, further comprising a center conduit disposed within theconduit, wherein the center conduit is configured to provide theoxidizing fluid into the opening during use, and wherein the conduit isfurther configured to remove an oxidation product during use.
 2792. Thesystem of claim 2780, wherein the portion of the formation extendsradially from the opening a width of less than approximately 0.2 m.2793. The system of claim 2780, further comprising a conductor disposedin a second conduit, wherein the second conduit is disposed within theopening, and wherein the conductor is configured to heat at least aportion of the formation during application of an electrical current tothe conductor.
 2794. The system of claim 2780, further comprising aninsulated conductor disposed within the opening, wherein the insulatedconductor is configured to heat at least a portion of the formationduring application of an electrical current to the insulated conductor.2795. The system of claim 2780, further comprising at least oneelongated member disposed within the opening, wherein the at least theone elongated member is configured to heat at least a portion of theformation during application of an electrical current to the at leastthe one elongated member.
 2796. The system of claim 2780, furthercomprising a heat exchanger disposed external to the formation, whereinthe heat exchanger is configured to heat the oxidizing fluid, whereinthe conduit is further configured to provide the heated oxidizing fluidinto the opening during use, and wherein the heated oxidizing fluid isconfigured to heat at least a portion of the formation during use. 2797.The system of claim 2780, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 2798. The system of claim 2780, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 2799. The system of claim2780, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 2800. The system of claim 2780, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening.
 2801. The system ofclaim 2780, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configured to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 2802. The system of claim2780, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 2803. The system of claim 2780, wherein the system isfurther configured such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 2804. A system configurable to heata coal formation, comprising: a heater configurable to be disposed in anopening in the formation, wherein the heater is further configurable toprovide heat to at least a portion of the formation during use; aconduit configurable to be disposed in the opening, wherein the conduitis configurable to provide an oxidizing fluid from an oxidizing fluidsource to a reaction zone in the formation during use, and wherein thesystem is configurable to allow the oxidizing fluid to oxidize at leastsome hydrocarbons at the reaction zone during use such that heat isgenerated at the reaction zone; and wherein the system is furtherconfigurable to allow heat to transfer substantially by conduction fromthe reaction zone to a pyrolysis zone of the formation during use. 2805.The system of claim 2804, wherein the oxidizing fluid is configurable togenerate heat in the reaction zone such that the oxidizing fluid istransported through the reaction zone substantially by diffusion. 2806.The system of claim 2804, wherein the conduit comprises orifices, andwherein the orifices are configurable to provide the oxidizing fluidinto the opening.
 2807. The system of claim 2804, wherein the conduitcomprises critical flow orifices, and wherein the critical flow orificesare configurable to control a flow of the oxidizing fluid such that arate of oxidation in the formation is controlled.
 2808. The system ofclaim 2804, wherein the conduit is further configurable to be cooledwith the oxidizing fluid such that the conduit is not substantiallyheated by oxidation.
 2809. The system of claim 2804, wherein the conduitis further configurable to remove an oxidation product.
 2810. The systemof claim 2804, wherein the conduit is further configurable to remove anoxidation product, such that the oxidation product transfers heat to theoxidizing fluid.
 2811. The system of claim 2804, wherein the conduit isfurther configurable to remove an oxidation product, and wherein a flowrate of the oxidizing fluid in the conduit is approximately equal to aflow rate of the oxidation product in the conduit.
 2812. The system ofclaim 2804, wherein the conduit is further configurable to remove anoxidation product, and wherein a pressure of the oxidizing fluid in theconduit and a pressure of the oxidation product in the conduit arecontrolled to reduce contamination of the oxidation product by theoxidizing fluid.
 2813. The system of claim 2804, wherein the conduit isfurther configurable to remove an oxidation product, and wherein theoxidation product is substantially inhibited from flowing into portionsof the formation beyond the reaction zone.
 2814. The system of claim2804, wherein the oxidizing fluid is substantially inhibited fromflowing into portions of the formation beyond the reaction zone. 2815.The system of claim 2804, further comprising a center conduit disposedwithin the conduit, wherein center conduit is configurable to providethe oxidizing fluid into the opening during use, and wherein the conduitis further configurable to remove an oxidation product during use. 2816.The system of claim 2804, wherein the portion of the formation extendsradially from the opening a width of less than approximately 0.2 m.2817. The system of claim 2804, further comprising a conductor disposedin a second conduit, wherein the second conduit is disposed within theopening, and wherein the conductor is configurable to heat at least aportion of the formation during application of an electrical current tothe conductor.
 2818. The system of claim 2804, further comprising aninsulated conductor disposed within the opening, wherein the insulatedconductor is configurable to heat at least a portion of the formationduring application of an electrical current to the insulated conductor.2819. The system of claim 2804, further comprising at least oneelongated member disposed within the opening, wherein the at least theone elongated member is configurable to heat at least a portion of theformation during application of an electrical current to the at leastthe one elongated member.
 2820. The system of claim 2804, furthercomprising a heat exchanger disposed external to the formation, whereinthe heat exchanger is configurable to heat the oxidizing fluid, whereinthe conduit is further configurable to provide the heated oxidizingfluid into the opening during use, and wherein the heated oxidizingfluid is configurable to heat at least a portion of the formation duringuse.
 2821. The system of claim 2804, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation.
 2822. The system of claim 2804,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 2823. The system of claim2804, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 2824. The system of claim 2804, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening.
 2825. The system ofclaim 2804, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configurable to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 2826. The system of claim2804, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 2827. The system of claim 2804, wherein the system isfurther configurable such that transferred heat can pyrolyze at leastsome hydrocarbons in the pyrolysis zone.
 2828. An in situ method forheating a coal formation, comprising: heating a portion of the formationto a temperature sufficient to support reaction of hydrocarbons withinthe portion of the formation with an oxidizing fluid; providing theoxidizing fluid to a reaction zone in the formation; allowing theoxidizing fluid to react with at least a portion of the hydrocarbons atthe reaction zone to generate heat at the reaction zone; andtransferring the generated heat substantially by conduction from thereaction zone to a pyrolysis zone in the formation.
 2829. The method ofclaim 2828, further comprising transporting the oxidizing fluid throughthe reaction zone by diffusion.
 2830. The method of claim 2828, furthercomprising directing at least a portion of the oxidizing fluid into theopening through orifices of a conduit disposed in the opening.
 2831. Themethod of claim 2828, further comprising controlling a flow of theoxidizing fluid with critical flow orifices of a conduit disposed in theopening such that a rate of oxidation is controlled.
 2832. The method ofclaim 2828, further comprising increasing a flow of the oxidizing fluidin the opening to accommodate an increase in a volume of the reactionzone such that a rate of oxidation is substantially constant over timewithin the reaction zone.
 2833. The method of claim 2828, wherein aconduit is disposed in the opening, the method further comprisingcooling the conduit with the oxidizing fluid to reduce heating of theconduit by oxidation.
 2834. The method of claim 2828, wherein a conduitis disposed within the opening, the method further comprising removingan oxidation product from the formation through the conduit.
 2835. Themethod of claim 2828, wherein a conduit is disposed within the opening,the method further comprising removing an oxidation product from theformation through the conduit and transferring heat from the oxidationproduct in the conduit to oxidizing fluid in the conduit.
 2836. Themethod of claim 2828, wherein a conduit is disposed within the opening,the method further comprising removing an oxidation product from theformation through the conduit, wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 2837. The method of claim 2828,wherein a conduit is disposed within the opening, the method furthercomprising removing an oxidation product from the formation through theconduit and controlling a pressure between the oxidizing fluid and theoxidation product in the conduit to reduce contamination of theoxidation product by the oxidizing fluid.
 2838. The method of claim2828, wherein a conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the conduit and substantially inhibiting the oxidation productfrom flowing into portions of the formation beyond the reaction zone.2839. The method of claim 2828, further comprising substantiallyinhibiting the oxidizing fluid from flowing into portions of theformation beyond the reaction zone.
 2840. The method of claim 2828,wherein a center conduit is disposed within an outer conduit, andwherein the outer conduit is disposed within the opening, the methodfurther comprising providing the oxidizing fluid into the openingthrough the center conduit and removing an oxidation product through theouter conduit.
 2841. The method of claim 2828, wherein the portion ofthe formation extends radially from the opening a width of less thanapproximately 0.2 m.
 2842. The method of claim 2828, wherein heating theportion comprises applying electrical current to a conductor disposed ina conduit, wherein the conduit is disposed within the opening.
 2843. Themethod of claim 2828, wherein heating the portion comprises applyingelectrical current to an insulated conductor disposed within theopening.
 2844. The method of claim 2828, wherein heating the portioncomprises applying electrical current to at least one elongated memberdisposed within the opening.
 2845. The method of claim 2828, whereinheating the portion comprises heating the oxidizing fluid in a heatexchanger disposed external to the formation such that providing theoxidizing fluid into the opening comprises transferring heat from theheated oxidizing fluid to the portion.
 2846. The method of claim 2828,further comprising removing water from the formation prior to heatingthe portion.
 2847. The method of claim 2828, further comprisingcontrolling the temperature of the formation to substantially inhibitproduction of oxides of nitrogen during oxidation.
 2848. The method ofclaim 2828, further comprising coupling an overburden casing to theopening, wherein the overburden casing is disposed in an overburden ofthe formation.
 2849. The method of claim 2828, further comprisingcoupling an overburden casing to the opening, wherein the overburdencasing is disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 2850. The method of claim 2828,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 2851. Themethod of claim 2828, further comprising coupling an overburden casingto the opening, wherein a packing material is disposed at a junction ofthe overburden casing and the opening.
 2852. The method of claim 2828,wherein the pyrolysis zone is substantially adjacent to the reactionzone.
 2853. A system configured to heat a coal formation, comprising: aheater disposed in an opening in the formation, wherein the heater isconfigured to provide heat to at least a portion of the formation duringuse; an oxidizing fluid source; a conduit disposed in the opening,wherein the conduit is configured to provide an oxidizing fluid from theoxidizing fluid source to a reaction zone in the formation during use,wherein the oxidizing fluid is selected to oxidize at least somehydrocarbons at the reaction zone during use such that heat is generatedat the reaction zone, and wherein the conduit is further configured toremove an oxidation product from the formation during use; and whereinthe system is configured to allow heat to transfer substantially byconduction from the reaction zone to a pyrolysis zone of the formationduring use.
 2854. The system of claim 2853, wherein the oxidizing fluidis configured to generate heat in the reaction zone such that theoxidizing fluid is transported through the reaction zone substantiallyby diffusion.
 2855. The system of claim 2853, wherein the conduitcomprises orifices, and wherein the orifices are configured to providethe oxidizing fluid into the opening.
 2856. The system of claim 2853,wherein the conduit comprises critical flow orifices, and wherein thecritical flow orifices are configured to control a flow of the oxidizingfluid such that a rate of oxidation in the formation is controlled.2857. The system of claim 2853, wherein the conduit is furtherconfigured to be cooled with the oxidizing fluid such that the conduitis not substantially heated by oxidation.
 2858. The system of claim2853, wherein the conduit is further configured such that the oxidationproduct transfers heat to the oxidizing fluid.
 2859. The system of claim2853, wherein a flow rate of the oxidizing fluid in the conduit isapproximately equal to a flow rate of the oxidation product in theconduit.
 2860. The system of claim 2853, wherein a pressure of theoxidizing fluid in the conduit and a pressure of the oxidation productin the conduit are controlled to reduce contamination of the oxidationproduct by the oxidizing fluid.
 2861. The system of claim 2853, whereinthe oxidation product is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 2862. The system ofclaim 2853, wherein the oxidizing fluid is substantially inhibited fromflowing into portions of the formation beyond the reaction zone. 2863.The system of claim 2853, further comprising a center conduit disposedwithin the conduit, wherein the center conduit is configured to providethe oxidizing fluid into the opening during use.
 2864. The system ofclaim 2853, wherein the portion of the formation extends radially fromthe opening a width of less than approximately 0.2 m.
 2865. The systemof claim 2853, further comprising a conductor disposed in a secondconduit, wherein the second conduit is disposed within the opening, andwherein the conductor is configured to heat at least a portion of theformation during application of an electrical current to the conductor.2866. The system of claim 2853, further comprising an insulatedconductor disposed within the opening, wherein the insulated conductoris configured to heat at least a portion of the formation duringapplication of an electrical current to the insulated conductor. 2867.The system of claim 2853, further comprising at least one elongatedmember disposed within the opening, wherein the at least the oneelongated member is configured to heat at least a portion of theformation during application of an electrical current to the at leastthe one elongated member.
 2868. The system of claim 2853, furthercomprising a heat exchanger disposed external to the formation, whereinthe heat exchanger is configured to heat the oxidizing fluid, whereinthe conduit is further configured to provide the heated oxidizing fluidinto the opening during use, and wherein the heated oxidizing fluid isconfigured to heat at least a portion of the formation during use. 2869.The system of claim 2853, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 2870. The system of claim 2853, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 2871. The system of claim2853, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 2872. The system of claim 2853, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening.
 2873. The system ofclaim 2853, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configured to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 2874. The system of claim2853, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 2875. The system of claim 2853, wherein the system isfurther configured such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 2876. A system configurable to heata coal formation, comprising: a heater configurable to be disposed in anopening in the formation, wherein the heater is further configurable toprovide heat to at least a portion of the formation during use; aconduit configurable to be disposed in the opening, wherein the conduitis further configurable to provide an oxidizing fluid from an oxidizingfluid source to a reaction zone in the formation during use, wherein thesystem is configurable to allow the oxidizing fluid to oxidize at leastsome hydrocarbons at the reaction zone during use such that heat isgenerated at the reaction zone, and wherein the conduit is furtherconfigurable to remove an oxidation product from the formation duringuse; and wherein the system is further configurable to allow heat totransfer substantially by conduction from the reaction zone to apyrolysis zone during use.
 2877. The system of claim 2876, wherein theoxidizing fluid is configurable to generate heat in the reaction zonesuch that the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 2878. The system of claim 2876, wherein theconduit comprises orifices, and wherein the orifices are configurable toprovide the oxidizing fluid into the opening.
 2879. The system of claim2876, wherein the conduit comprises critical flow orifices, and whereinthe critical flow orifices are configurable to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 2880. The system of claim 2876, wherein the conduit isfurther configurable to be cooled with the oxidizing fluid such that theconduit is not substantially heated by oxidation.
 2881. The system ofclaim 2876, wherein the conduit is further configurable such that theoxidation product transfers heat to the oxidizing fluid.
 2882. Thesystem of claim 2876, wherein a flow rate of the oxidizing fluid in theconduit is approximately equal to a flow rate of the oxidation productin the conduit.
 2883. The system of claim 2876, wherein a pressure ofthe oxidizing fluid in the conduit and a pressure of the oxidationproduct in the conduit are controlled to reduce contamination of theoxidation product by the oxidizing fluid.
 2884. The system of claim2876, wherein the oxidation product is substantially inhibited fromflowing into portions of the formation beyond the reaction zone. 2885.The system of claim 2876, wherein the oxidizing fluid is substantiallyinhibited from flowing into portions of the formation beyond thereaction zone.
 2886. The system of claim 2876, further comprising acenter conduit disposed within the conduit, wherein center conduit isconfigurable to provide the oxidizing fluid into the opening during use.2887. The system of claim 2876, wherein the portion of the formationextends radially from the opening a width of less than approximately 0.2m.
 2888. The system of claim 2876, further comprising a conductordisposed in a second conduit, wherein the second conduit is disposedwithin the opening, and wherein the conductor is configurable to heat atleast a portion of the formation during application of an electricalcurrent to the conductor.
 2889. The system of claim 2876, furthercomprising an insulated conductor disposed within the opening, whereinthe insulated conductor is configurable to heat at least a portion ofthe formation during application of an electrical current to theinsulated conductor.
 2890. The system of claim 2876, further comprisingat least one elongated member disposed within the opening, wherein theat least the one elongated member is configurable to heat at least aportion of the formation during application of an electrical current tothe at least the one elongated member.
 2891. The system of claim 2876,further comprising a heat exchanger disposed external to the formation,wherein the heat exchanger is configurable to heat the oxidizing fluid,wherein the conduit is further configurable to provide the heatedoxidizing fluid into the opening during use, and wherein the heatedoxidizing fluid is configurable to heat at least a portion of theformation during use.
 2892. The system of claim 2876, further comprisingan overburden casing coupled to the opening, wherein the overburdencasing is disposed in an overburden of the formation.
 2893. The systemof claim 2876, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, and wherein the overburden casing comprises steel. 2894.The system of claim 2876, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 2895. The system of claim 2876, furthercomprising an overburden casing coupled to the opening, wherein apacking material is disposed at a junction of the overburden casing andthe opening.
 2896. The system of claim 2876, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and theopening, and wherein the packing material is configurable tosubstantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 2897. The system of claim 2876, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.2898. The system of claim 2876, wherein the system is furtherconfigurable such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 2899. An in situ method for heatinga coal formation, comprising: heating a portion of the formation to atemperature sufficient to support reaction of hydrocarbons within theportion of the formation with an oxidizing fluid, wherein the portion islocated substantially adjacent to an opening in the formation; providingthe oxidizing fluid to a reaction zone in the formation; allowing theoxidizing gas to react with at least a portion of the hydrocarbons atthe reaction zone to generate heat in the reaction zone; removing atleast a portion of an oxidation product through the opening; andtransferring the generated heat substantially by conduction from thereaction zone to a pyrolysis zone in the formation.
 2900. The method ofclaim 2899, further comprising transporting the oxidizing fluid throughthe reaction zone by diffusion.
 2901. The method of claim 2899, furthercomprising directing at least a portion of the oxidizing fluid into theopening through orifices of a conduit disposed in the opening.
 2902. Themethod of claim 2899, further comprising controlling a flow of theoxidizing fluid with critical flow orifices of a conduit disposed in theopening such that a rate of oxidation is controlled.
 2903. The method ofclaim 2899, further comprising increasing a flow of the oxidizing fluidin the opening to accommodate an increase in a volume of the reactionzone such that a rate of oxidation is substantially maintained withinthe reaction zone.
 2904. The method of claim 2899, wherein a conduit isdisposed in the opening, the method further comprising cooling theconduit with the oxidizing fluid such that the conduit is notsubstantially heated by oxidation.
 2905. The method of claim 2899,wherein a conduit is disposed within the opening, and wherein removingat least the portion of the oxidation product through the openingcomprises removing at least the portion of the oxidation product throughthe conduit.
 2906. The method of claim 2899, wherein a conduit isdisposed within the opening, and wherein removing at least the portionof the oxidation product through the opening comprises removing at leastthe portion of the oxidation product through the conduit, the methodfurther comprising transferring substantial heat from the oxidationproduct in the conduit to the oxidizing fluid in the conduit.
 2907. Themethod of claim 2899, wherein a conduit is disposed within the opening,wherein removing at least the portion of the oxidation product throughthe opening comprises removing at least the portion of the oxidationproduct through the conduit, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 2908. The method of claim 2899,wherein a conduit is disposed within the opening, and wherein removingat least the portion of the oxidation product through the openingcomprises removing at least the portion of the oxidation product throughthe conduit, the method further comprising controlling a pressurebetween the oxidizing fluid and the oxidation product in the conduit toreduce contamination of the oxidation product by the oxidizing fluid.2909. The method of claim 2899, wherein a conduit is disposed within theopening, and wherein removing at least the portion of the oxidationproduct through the opening comprises removing at least the portion ofthe oxidation product through the conduit, the method further comprisingsubstantially inhibiting the oxidation product from flowing intoportions of the formation beyond the reaction zone.
 2910. The method ofclaim 2899, further comprising substantially inhibiting the oxidizingfluid from flowing into portions of the formation beyond the reactionzone.
 2911. The method of claim 2899, wherein a center conduit isdisposed within an outer conduit, and wherein the outer conduit isdisposed within the opening, the method further comprising providing theoxidizing fluid into the opening through the center conduit and removingat least a portion of the oxidation product through the outer conduit.2912. The method of claim 2899, wherein the portion of the formationextends radially from the opening a width of less than approximately 0.2m.
 2913. The method of claim 2899, wherein heating the portion comprisesapplying electrical current to a conductor disposed in a conduit,wherein the conduit is disposed within the opening.
 2914. The method ofclaim 2899, wherein heating the portion comprises applying electricalcurrent to an insulated conductor disposed within the opening.
 2915. Themethod of claim 2899, wherein heating the portion comprises applyingelectrical current to at least one elongated member disposed within theopening.
 2916. The method of claim 2899, wherein heating the portioncomprises heating the oxidizing fluid in a heat exchanger disposedexternal to the formation such that providing the oxidizing fluid intothe opening comprises transferring heat from the heated oxidizing fluidto the portion.
 2917. The method of claim 2899, further comprisingremoving water from the formation prior to heating the portion. 2918.The method of claim 2899, further comprising controlling the temperatureof the formation to substantially inhibit production of oxides ofnitrogen during oxidation.
 2919. The method of claim 2899, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 2920.The method of claim 2899, further comprising coupling an overburdencasing to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 2921. The method of claim 2899, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing is further disposed in cement.
 2922. The method of claim 2899,further comprising coupling an overburden casing to the opening, whereina packing material is disposed at a junction of the overburden casingand the opening.
 2923. The method of claim 2899, wherein the pyrolysiszone is substantially adjacent to the reaction.
 2924. A systemconfigured to heat a coal formation, comprising: an electric heaterdisposed in an opening in the formation, wherein the electric heater isconfigured to provide heat to at least a portion of the formation duringuse; an oxidizing fluid source; a conduit disposed in the opening,wherein the conduit is configured to provide an oxidizing fluid from theoxidizing fluid source to a reaction zone in the formation during use,and wherein the oxidizing fluid is selected to oxidize at least somehydrocarbons at the reaction zone during use such that heat is generatedat the reaction zone; and wherein the system is configured to allow heatto transfer substantially by conduction from the reaction zone to apyrolysis zone of the formation during use.
 2925. The system of claim2924, wherein the oxidizing fluid is configured to generate heat in thereaction zone such that the oxidizing fluid is transported through thereaction zone substantially by diffusion.
 2926. The system of claim2924, wherein the conduit comprises orifices, and wherein the orificesare configured to provide the oxidizing fluid into the opening. 2927.The system of claim 2924, wherein the conduit comprises critical floworifices, and wherein the critical flow orifices are configured tocontrol a flow of the oxidizing fluid such that a rate of oxidation inthe formation is controlled.
 2928. The system of claim 2924, wherein theconduit is further configured to be cooled with the oxidizing fluid suchthat the conduit is not substantially heated by oxidation.
 2929. Thesystem of claim 2924, wherein the conduit is further configured toremove an oxidation product.
 2930. The system of claim 2924, wherein theconduit is further configured to remove an oxidation product, such thatthe oxidation product transfers heat to the oxidizing fluid.
 2931. Thesystem of claim 2924, wherein the conduit is further configured toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 2932. The system of claim 2924,wherein the conduit is further configured to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.2933. The system of claim 2924, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 2934. The system of claim 2924,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 2935. The system ofclaim 2924, further comprising a center conduit disposed within theconduit, wherein the center conduit is configured to provide theoxidizing fluid into the opening during use, and wherein the conduit isfurther configured to remove an oxidation product during use.
 2936. Thesystem of claim 2924, wherein the portion of the formation extendsradially from the opening a width of less than approximately 0.2 m.2937. The system of claim 2924, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 2938. The system of claim 2924, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 2939. The system of claim2924, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 2940. The system of claim 2924, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening.
 2941. The system ofclaim 2924, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configured to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 2942. The system of claim2924, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 2943. The system of claim 2924, wherein the system isfurther configured such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 2944. A system configurable to heata coal formation, comprising: an electric heater configurable to bedisposed in an opening in the formation, wherein the electric heater isfurther configurable to provide heat to at least a portion of theformation during use, and wherein at least the portion is locatedsubstantially adjacent to the opening; a conduit configurable to bedisposed in the opening, wherein the conduit is further configurable toprovide an oxidizing fluid from an oxidizing fluid source to a reactionzone in the formation during use, and wherein the system is configurableto allow the oxidizing fluid to oxidize at least some hydrocarbons atthe reaction zone during use such that heat is generated at the reactionzone; and wherein the system is further configurable to allow heat totransfer substantially by conduction from the reaction zone to apyrolysis zone of the formation during use.
 2945. The system of claim2944, wherein the oxidizing fluid is configurable to generate heat inthe reaction zone such that the oxidizing fluid is transported throughthe reaction zone substantially by diffusion.
 2946. The system of claim2944, wherein the conduit comprises orifices, and wherein the orificesare configurable to provide the oxidizing fluid into the opening. 2947.The system of claim 2944, wherein the conduit comprises critical floworifices, and wherein the critical flow orifices are configurable tocontrol a flow of the oxidizing fluid such that a rate of oxidation inthe formation is controlled.
 2948. The system of claim 2944, wherein theconduit is further configurable to be cooled with the oxidizing fluidsuch that the conduit is not substantially heated by oxidation. 2949.The system of claim 2944, wherein the conduit is further configurable toremove an oxidation product.
 2950. The system of claim 2944, wherein theconduit is further configurable to remove an oxidation product such thatthe oxidation product transfers heat to the oxidizing fluid.
 2951. Thesystem of claim 2944, wherein the conduit is further configurable toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 2952. The system of claim 2944,wherein the conduit is further configurable to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.2953. The system of claim 2944, wherein the conduit is furtherconfigurable to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 2954. The system of claim 2944,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 2955. The system ofclaim 2944, further comprising a center conduit disposed within theconduit, wherein center conduit is configurable to provide the oxidizingfluid into the opening during use, and wherein the conduit is furtherconfigurable to remove an oxidation product during use.
 2956. The systemof claim 2944, wherein the portion of the formation extends radiallyfrom the opening a width of less than approximately 0.2 m.
 2957. Thesystem of claim 2944, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation.
 2958. The system of claim 2944, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 2959. The system of claim 2944,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 2960. Thesystem of claim 2944, further comprising an overburden casing coupled tothe opening, wherein a packing material is disposed at a junction of theoverburden casing and the opening.
 2961. The system of claim 2944,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation,wherein a packing material is disposed at a junction of the overburdencasing and the opening, and wherein the packing material is configurableto substantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 2962. The system of claim 2944, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.2963. The system of claim 2944, wherein the system is furtherconfigurable such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 2964. A system configured to heat acoal formation, comprising: a conductor disposed in a first conduit,wherein the first conduit is disposed in an opening in the formation,and wherein the conductor is configured to provide heat to at least aportion of the formation during use; an oxidizing fluid source; a secondconduit disposed in the opening, wherein the second conduit isconfigured to provide an oxidizing fluid from the oxidizing fluid sourceto a reaction zone in the formation during use, and wherein theoxidizing fluid is selected to oxidize at least some hydrocarbons at thereaction zone during use such that heat is generated at the reactionzone; and wherein the system is configured to allow heat to transfersubstantially by conduction from the reaction zone to a pyrolysis zoneof the formation during use.
 2965. The system of claim 2964, wherein theoxidizing fluid is configured to generate heat in the reaction zone suchthat the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 2966. The system of claim 2964, wherein thesecond conduit comprises orifices, and wherein the orifices areconfigured to provide the oxidizing fluid into the opening.
 2967. Thesystem of claim 2964, wherein the second conduit comprises critical floworifices, and wherein the critical flow orifices are configured tocontrol a flow of the oxidizing fluid such that a rate of oxidation inthe formation is controlled.
 2968. The system of claim 2964, wherein thesecond conduit is further configured to be cooled with the oxidizingfluid to reduce heating of the second conduit by oxidation.
 2969. Thesystem of claim 2964, wherein the second conduit is further configuredto remove an oxidation product.
 2970. The system of claim 2964, whereinthe second conduit is further configured to remove an oxidation productsuch that the oxidation product transfers heat to the oxidizing fluid.2971. The system of claim 2964, wherein the second conduit is furtherconfigured to remove an oxidation product, and wherein a flow rate ofthe oxidizing fluid in the conduit is approximately equal to a flow rateof the oxidation product in the second conduit.
 2972. The system ofclaim 2964, wherein the second conduit is further configured to removean oxidation product, and wherein a pressure of the oxidizing fluid inthe second conduit and a pressure of the oxidation product in the secondconduit are controlled to reduce contamination of the oxidation productby the oxidizing fluid.
 2973. The system of claim 2964, wherein thesecond conduit is further configured to remove an oxidation product, andwherein the oxidation product is substantially inhibited from flowinginto portions of the formation beyond the reaction zone.
 2974. Thesystem of claim 2964, wherein the oxidizing fluid is substantiallyinhibited from flowing into portions of the formation beyond thereaction zone.
 2975. The system of claim 2964, further comprising acenter conduit disposed within the second conduit, wherein the centerconduit is configured to provide the oxidizing fluid into the openingduring use, and wherein the second conduit is further configured toremove an oxidation product during use.
 2976. The system of claim 2964,wherein the portion of the formation extends radially from the opening awidth of less than approximately 0.2 m.
 2977. The system of claim 2964,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation.2978. The system of claim 2964, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 2979. The system of claim 2964, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 2980. The system of claim 2964, furthercomprising an overburden casing coupled to the opening, wherein apacking material is disposed at a junction of the overburden casing andthe opening.
 2981. The system of claim 2964, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and theopening, and wherein the packing material is configured to substantiallyinhibit a flow of fluid between the opening and the overburden casingduring use.
 2982. The system of claim 2964, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and theopening, and wherein the packing material comprises cement.
 2983. Thesystem of claim 2964, wherein the system is further configured such thattransferred heat can pyrolyze at least some hydrocarbons in thepyrolysis zone.
 2984. A system configurable to heat a coal formation,comprising: a conductor configurable to be disposed in a first conduit,wherein the first conduit is configurable to be disposed in an openingin the formation, and wherein the conductor is further configurable toprovide heat to at least a portion of the formation during use; a secondconduit configurable to be disposed in the opening, wherein the secondconduit is further configurable to provide an oxidizing fluid from anoxidizing fluid source to a reaction zone in the formation during use,and wherein the system is configurable to allow the oxidizing fluid tooxidize at least some hydrocarbons at the reaction zone during use suchthat heat is generated at the reaction zone; and wherein the system isfurther configurable to allow heat to transfer substantially byconduction from the reaction zone to a pyrolysis zone of the formationduring use.
 2985. The system of claim 2984, wherein the oxidizing fluidis configurable to generate heat in the reaction zone such that theoxidizing fluid is transported through the reaction zone substantiallyby diffusion.
 2986. The system of claim 2984, wherein the second conduitcomprises orifices, and wherein the orifices are configurable to providethe oxidizing fluid into the opening.
 2987. The system of claim 2984,wherein the second conduit comprises critical flow orifices, and whereinthe critical flow orifices are configurable to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 2988. The system of claim 2984, wherein the second conduitis further configurable to be cooled with the oxidizing fluid to reduceheating of the second conduit by oxidation.
 2989. The system of claim2984, wherein the second conduit is further configurable to remove anoxidation product.
 2990. The system of claim 2984, wherein the secondconduit is further configurable to remove an oxidation product such thatthe oxidation product transfers heat to the oxidizing fluid.
 2991. Thesystem of claim 2984, wherein the second conduit is further configurableto remove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the second conduit.
 2992. The system of claim 2984,wherein the second conduit is further configurable to remove anoxidation product, and wherein a pressure of the oxidizing fluid in thesecond conduit and a pressure of the oxidation product in the secondconduit are controlled to reduce contamination of the oxidation productby the oxidizing fluid.
 2993. The system of claim 2984, wherein thesecond conduit is further configurable to remove an oxidation product,and wherein the oxidation product is substantially inhibited fromflowing into portions of the formation beyond the reaction zone. 2994.The system of claim 2984, wherein the oxidizing fluid is substantiallyinhibited from flowing into portions of the formation beyond thereaction zone.
 2995. The system of claim 2984, further comprising acenter conduit disposed within the second conduit, wherein centerconduit is configurable to provide the oxidizing fluid into the openingduring use, and wherein the second conduit is further configurable toremove an oxidation product during use.
 2996. The system of claim 2984,wherein the portion of the formation extends radially from the opening awidth of less than approximately 0.2 m.
 2997. The system of claim 2984,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation.2998. The system of claim 2984, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 2999. The system of claim 2984, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3000. The system of claim 2984, furthercomprising an overburden casing coupled to the opening, wherein apacking material is disposed at a junction of the overburden casing andthe opening.
 3001. The system of claim 2984, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and theopening, and wherein the packing material is configurable tosubstantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 3002. The system of claim 2984, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3003. The system of claim 2984, wherein the system is furtherconfigurable such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 3004. An in situ method for heatinga coal formation, comprising: heating a portion of the formation to atemperature sufficient to support reaction of hydrocarbons within theportion of the formation with an oxidizing fluid, wherein heatingcomprises applying an electrical current to a conductor disposed in afirst conduit to provide heat to the portion, and wherein the firstconduit is disposed within the opening; providing the oxidizing fluid toa reaction zone in the formation; allowing the oxidizing fluid to reactwith at least a portion of the hydrocarbons at the reaction zone togenerate heat at the reaction zone; and transferring the generated heatsubstantially by conduction from the reaction zone to a pyrolysis zonein the formation.
 3005. The method of claim 3004, further comprisingtransporting the oxidizing fluid through the reaction zone by diffusion.3006. The method of claim 3004, further comprising directing at least aportion of the oxidizing fluid into the opening through orifices of asecond conduit disposed in the opening.
 3007. The method of claim 3004,further comprising controlling a flow of the oxidizing fluid withcritical flow orifices of a second conduit disposed in the opening suchthat a rate of oxidation is controlled.
 3008. The method of claim 3004,further comprising increasing a flow of the oxidizing fluid in theopening to accommodate an increase in a volume of the reaction zone suchthat a rate of oxidation is substantially constant over time within thereaction zone.
 3009. The method of claim 3004, wherein a second conduitis disposed in the opening, the method further comprising cooling thesecond conduit with the oxidizing fluid to reduce heating of the secondconduit by oxidation.
 3010. The method of claim 3004, wherein a secondconduit is disposed within the opening, the method further comprisingremoving an oxidation product from the formation through the secondconduit.
 3011. The method of claim 3004, wherein a second conduit isdisposed within the opening, the method further comprising removing anoxidation product from the formation through the second conduit andtransferring heat from the oxidation product in the conduit to theoxidizing fluid in the second conduit.
 3012. The method of claim 3004,wherein a second conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the second conduit, wherein a flow rate of the oxidizing fluidin the second conduit is approximately equal to a flow rate of theoxidation product in the second conduit.
 3013. The method of claim 3004,wherein a second conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the second conduit and controlling a pressure between theoxidizing fluid and the oxidation product in the second conduit toreduce contamination of the oxidation product by the oxidizing fluid.3014. The method of claim 3004, wherein a second conduit is disposedwithin the opening, the method further comprising removing an oxidationproduct from the formation through the conduit and substantiallyinhibiting the oxidation product from flowing into portions of theformation beyond the reaction zone.
 3015. The method of claim 3004,further comprising substantially inhibiting the oxidizing fluid fromflowing into portions of the formation beyond the reaction zone. 3016.The method of claim 3004, wherein a center conduit is disposed within anouter conduit, and wherein the outer conduit is disposed within theopening, the method further comprising providing the oxidizing fluidinto the opening through the center conduit and removing an oxidationproduct through the outer conduit.
 3017. The method of claim 3004,wherein the portion of the formation extends radially from the opening awidth of less than approximately 0.2 m.
 3018. The method of claim 3004,further comprising removing water from the formation prior to heatingthe portion.
 3019. The method of claim 3004, further comprisingcontrolling the temperature of the formation to substantially inhibitproduction of oxides of nitrogen during oxidation.
 3020. The method ofclaim 3004, further comprising coupling an overburden casing to theopening, wherein the overburden casing is disposed in an overburden ofthe formation.
 3021. The method of claim 3004, further comprisingcoupling an overburden casing to the opening, wherein the overburdencasing is disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3022. The method of claim 3004,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3023. Themethod of claim 3004, further comprising coupling an overburden casingto the opening, wherein a packing material is disposed at a junction ofthe overburden casing and the opening.
 3024. A system configured to heata coal formation, comprising: an insulated conductor disposed in anopening in the formation, wherein the insulated conductor is configuredto provide heat to at least a portion of the formation during use; anoxidizing fluid source: a conduit disposed in the opening, wherein theconduit is configured to provide an oxidizing fluid from the oxidizingfluid source to a reaction zone in the formation during use, and whereinthe oxidizing fluid is selected to oxidize at least some hydrocarbons atthe reaction zone during use such that heat is generated at the reactionzone; and wherein the system is configured to allow heat to transfersubstantially by conduction from the reaction zone to a pyrolysis zoneof the formation during use.
 3025. The system of claim 3024, wherein theoxidizing fluid is configured to generate heat in the reaction zone suchthat the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 3026. The system of claim 3024, wherein theconduit comprises orifices, and wherein the orifices are configured toprovide the oxidizing fluid into the opening.
 3027. The system of claim3024, wherein the conduit comprises critical flow orifices, and whereinthe critical flow orifices are configured to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 3028. The system of claim 3024, wherein the conduit isconfigured to be cooled with the oxidizing fluid such that the conduitis not substantially heated by oxidation.
 3029. The system of claim3024, wherein the conduit is further configured to remove an oxidationproduct.
 3030. The system of claim 3024, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein the conduit isfurther configured such that the oxidation product transfers substantialheat to the oxidizing fluid.
 3031. The system of claim 3024, wherein theconduit is further configured to remove an oxidation product, andwherein a flow rate of the oxidizing fluid in the conduit isapproximately equal to a flow rate of the oxidation product in theconduit.
 3032. The system of claim 3024, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein a pressure of theoxidizing fluid in the second conduit and a pressure of the oxidationproduct in the conduit are controlled to reduce contamination of theoxidation product by the oxidizing fluid.
 3033. The system of claim3024, wherein the conduit is further configured to remove an oxidationproduct, and wherein the oxidation product is substantially inhibitedfrom flowing into portions of the formation beyond the reaction zone.3034. The system of claim 3024, wherein the oxidizing fluid issubstantially inhibited from flowing into portions of the formationbeyond the reaction zone.
 3035. The system of claim 3024, furthercomprising a center conduit disposed within the conduit, wherein thecenter conduit is configured to provide the oxidizing fluid into theopening during use, and wherein the conduit is further configured toremove an oxidation product during use.
 3036. The system of claim 3024,wherein the portion of the formation extends radially from the opening awidth of less than approximately 0.2 m.
 3037. The system of claim 3024,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation.3038. The system of claim 3024, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3039. The system of claim 3024, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3040. The system of claim 3024, furthercomprising an overburden casing coupled to the opening, wherein apacking material is disposed at a junction of the overburden casing andthe opening.
 3041. The system of claim 3024, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and theopening, and wherein the packing material is configured to substantiallyinhibit a flow of fluid between the opening and the overburden casingduring use.
 3042. The system of claim 3024, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and theopening, and wherein the packing material comprises cement.
 3043. Thesystem of claim 3024, wherein the system is further configured such thattransferred heat can pyrolyze at least some hydrocarbons in thepyrolysis zone.
 3044. A system configurable to heat a coal formation,comprising: an insulated conductor configurable to be disposed in anopening in the formation, wherein the insulated conductor is furtherconfigurable to provide heat to at least a portion of the formationduring use; a conduit configurable to be disposed in the opening,wherein the conduit is further configurable to provide an oxidizingfluid from an oxidizing fluid source to a reaction zone in the formationduring use, and wherein the system is configurable to allow theoxidizing fluid to oxidize at least some hydrocarbons at the reactionzone during use such that heat is generated at the reaction zone; andwherein the system is further configurable to allow heat to transfersubstantially by conduction from the reaction zone to a pyrolysis zoneof the formation during use.
 3045. The system of claim 3044, wherein theoxidizing fluid is configurable to generate heat in the reaction zonesuch that the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 3046. The system of claim 3044, wherein theconduit comprises orifices, and wherein the orifices are configurable toprovide the oxidizing fluid into the opening.
 3047. The system of claim3044, wherein the conduit comprises critical flow orifices, and whereinthe critical flow orifices are configurable to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 3048. The system of claim 3044, wherein the conduit isfurther configurable to be cooled with the oxidizing fluid such that theconduit is not substantially heated by oxidation.
 3049. The system ofclaim 3044, wherein the conduit is further configurable to remove anoxidation product.
 3050. The system of claim 3044, wherein the conduitis further configurable to remove an oxidation product, such that theoxidation product transfers heat to the oxidizing fluid.
 3051. Thesystem of claim 3044, wherein the conduit is further configurable toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 3052. The system of claim 3044,wherein the conduit is further configurable to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.3053. The system of claim 3044, wherein the conduit is furtherconfigurable to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 3054. The system of claim 3044,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 3055. The system ofclaim 3044, further comprising a center conduit disposed within theconduit, wherein center conduit is configurable to provide the oxidizingfluid into the opening during use, and wherein the conduit is furtherconfigurable to remove an oxidation product during use.
 3056. The systemof claim 3044, wherein the portion of the formation extends radiallyfrom the opening a width of less than approximately 0.2 m.
 3057. Thesystem of claim 3044, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation.
 3058. The system of claim 3044, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3059. The system of claim 3044,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3060. Thesystem of claim 3044, further comprising an overburden casing coupled tothe opening, wherein a packing material is disposed at a junction of theoverburden casing and the opening.
 3061. The system of claim 3044,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation,wherein a packing material is disposed at a junction of the overburdencasing and the opening, and wherein the packing material is configurableto substantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 3062. The system of claim 3044, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3063. The system of claim 3044, wherein the system is furtherconfigurable such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 3064. An in situ method for heatinga coal formation, comprising: heating a portion of the formation to atemperature sufficient to support reaction of hydrocarbons within theportion of the formation with an oxidizing fluid, wherein heatingcomprises applying an electrical current to an insulated conductor toprovide heat to the portion, and wherein the insulated conductor isdisposed within the opening; providing the oxidizing fluid to a reactionzone in the formation; allowing the oxidizing fluid to react with atleast a portion of the hydrocarbons at the reaction zone to generateheat at the reaction zone; and transferring the generated heatsubstantially by conduction from the reaction zone to a pyrolysis zonein the formation.
 3065. The method of claim 3064, further comprisingtransporting the oxidizing fluid through the reaction zone by diffusion.3066. The method of claim 3064, further comprising directing at least aportion of the oxidizing fluid into the opening through orifices of aconduit disposed in the opening.
 3067. The method of claim 3064, furthercomprising controlling a flow of the oxidizing fluid with critical floworifices of a conduit disposed in the opening such that a rate ofoxidation is controlled.
 3068. The method of claim 3064, furthercomprising increasing a flow of the oxidizing fluid in the opening toaccommodate an increase in a volume of the reaction zone such that arate of oxidation is substantially constant over time within thereaction zone.
 3069. The method of claim 3064, wherein a conduit isdisposed in the opening, the method further comprising cooling theconduit with the oxidizing fluid to reduce heating of the conduit byoxidation.
 3070. The method of claim 3064, wherein a conduit is disposedwithin the opening, the method further comprising removing an oxidationproduct from the formation through the conduit.
 3071. The method ofclaim 3064, wherein a conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the conduit and transferring heat from the oxidation product inthe conduit to the oxidizing fluid in the conduit.
 3072. The method ofclaim 3064, wherein a conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the conduit, wherein a flow rate of the oxidizing fluid in theconduit is approximately equal to a flow rate of the oxidation productin the conduit.
 3073. The method of claim 3064, wherein a conduit isdisposed within the opening, the method further comprising removing anoxidation product from the formation through the conduit and controllinga pressure between the oxidizing fluid and the oxidation product in theconduit to reduce contamination of the oxidation product by theoxidizing fluid.
 3074. The method of claim 3064, wherein a conduit isdisposed within the opening, the method further comprising removing anoxidation product from the formation through the conduit andsubstantially inhibiting the oxidation product from flowing intoportions of the formation beyond the reaction zone.
 3075. The method ofclaim 3064, further comprising substantially inhibiting the oxidizingfluid from flowing into portions of the formation beyond the reactionzone.
 3076. The method of claim 3064, wherein a center conduit isdisposed within an outer conduit, and wherein the outer conduit isdisposed within the opening, the method further comprising providing theoxidizing fluid into the opening through the center conduit and removingan oxidation product through the outer conduit.
 3077. The method ofclaim 3064, wherein the portion of the formation extends radially fromthe opening a width of less than approximately 0.2 m.
 3078. The methodof claim 3064, further comprising removing water from the formationprior to heating the portion.
 3079. The method of claim 3064, furthercomprising controlling the temperature of the formation to substantiallyinhibit production of oxides of nitrogen during oxidation.
 3080. Themethod of claim 3064, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3081. The method of claim 3064, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3082. The method of claim3064, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3083. The method of claim 3064, further comprising coupling anoverburden casing to the opening, wherein a packing material is disposedat a junction of the overburden casing and the opening.
 3084. The methodof claim 3064, wherein the pyrolysis zone is substantially adjacent tothe reaction zone.
 3085. An in situ method for heating a coal formation,comprising: heating a portion of the formation to a temperaturesufficient to support reaction of hydrocarbons within the portion of theformation with an oxidizing fluid, wherein the portion is locatedsubstantially adjacent to an opening in the formation, wherein heatingcomprises applying an electrical current to an insulated conductor toprovide heat to the portion, wherein the insulated conductor is coupledto a conduit, wherein the conduit comprises critical flow orifices, andwherein the conduit is disposed within the opening; providing theoxidizing fluid to a reaction zone in the formation; allowing theoxidizing fluid to react with at least a portion of the hydrocarbons atthe reaction zone to generate heat at the reaction zone; andtransferring the generated heat substantially by conduction from thereaction zone to a pyrolysis zone in the formation.
 3086. The method ofclaim 3085, further comprising transporting the oxidizing fluid throughthe reaction zone by diffusion.
 3087. The method of claim 3085, furthercomprising controlling a flow of the oxidizing fluid with the criticalflow orifices such that a rate of oxidation is controlled.
 3088. Themethod of claim 3085, further comprising increasing a flow of theoxidizing fluid in the opening to accommodate an increase in a volume ofthe reaction zone such that a rate of oxidation is substantiallyconstant over time within the reaction zone.
 3089. The method of claim3085, further comprising cooling the conduit with the oxidizing fluid toreduce heating of the conduit by oxidation.
 3090. The method of claim3085, further comprising removing an oxidation product from theformation through the conduit.
 3091. The method of claim 3085, furthercomprising removing an oxidation product from the formation through theconduit and transferring heat from the oxidation product in the conduitto the oxidizing fluid in the conduit.
 3092. The method of claim 3085,further comprising removing an oxidation product from the formationthrough the conduit, wherein a flow rate of the oxidizing fluid in theconduit is approximately equal to a flow rate of the oxidation productin the conduit.
 3093. The method of claim 3085, further comprisingremoving an oxidation product from the formation through the conduit andcontrolling a pressure between the oxidizing fluid and the oxidationproduct in the conduit to reduce contamination of the oxidation productby the oxidizing fluid.
 3094. The method of claim 3085, furthercomprising removing an oxidation product from the formation through theconduit and substantially inhibiting the oxidation product from flowinginto portions of the formation beyond the reaction zone.
 3095. Themethod of claim 3085, further comprising substantially inhibiting theoxidizing fluid from flowing into portions of the formation beyond thereaction zone.
 3096. The method of claim 3085, wherein a center conduitis disposed within the conduit, the method further comprising providingthe oxidizing fluid into the opening through the center conduit andremoving an oxidation product through the conduit.
 3097. The method ofclaim 3085, wherein the portion of the formation extends radially fromthe opening a width of less than approximately 0.2 m.
 3098. The methodof claim 3085, further comprising removing water from the formationprior to heating the portion.
 3099. The method of claim 3085, furthercomprising controlling the temperature of the formation to substantiallyinhibit production of oxides of nitrogen during oxidation.
 3100. Themethod of claim 3085, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3101. The method of claim 3085, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3102. The method of claim3085, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3103. The method of claim 3085, further comprising coupling anoverburden casing to the opening, wherein a packing material is disposedat a junction of the overburden casing and the opening.
 3104. The methodof claim 3085, wherein the pyrolysis zone is substantially adjacent tothe reaction zone.
 3105. A system configured to heat a coal formation,comprising: at least one elongated member disposed in an opening in theformation, wherein at least the one elongated member is configured toprovide heat to at least a portion of the formation during use; anoxidizing fluid source; a conduit disposed in the opening, wherein theconduit is configured to provide an oxidizing fluid from the oxidizingfluid source to a reaction zone in the formation during use, and whereinthe oxidizing fluid is selected to oxidize at least some hydrocarbons atthe reaction zone during use such that heat is generated at the reactionzone; and wherein the system is configured to allow heat to transfersubstantially by conduction from the reaction zone to a pyrolysis zoneof the formation during use.
 3106. The system of claim 3105, wherein theoxidizing fluid is configured to generate heat in the reaction zone suchthat the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 3107. The system of claim 3105, wherein theconduit comprises orifices, and wherein the orifices are configured toprovide the oxidizing fluid into the opening.
 3108. The system of claim3105, wherein the conduit comprises critical flow orifices, and whereinthe critical flow orifices are configured to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 3109. The system of claim 3105, wherein the conduit isfurther configured to be cooled with the oxidizing fluid such that theconduit is not substantially heated by oxidation.
 3110. The system ofclaim 3105, wherein the conduit is further configured to remove anoxidation product.
 3111. The system of claim 3105, wherein the conduitis further configured to remove an oxidation product such that theoxidation product transfers heat to the oxidizing fluid.
 3112. Thesystem of claim 3105, wherein the conduit is further configured toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 3113. The system of claim 3105,wherein the conduit is further configured to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.3114. The system of claim 3105, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 3115. The system of claim 3105,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 3116. The system ofclaim 3105, further comprising a center conduit disposed within theconduit, wherein the center conduit is configured to provide theoxidizing fluid into the opening during use, and wherein the conduit isfurther configured to remove an oxidation product during use.
 3117. Thesystem of claim 3105, wherein the portion of the formation extendsradially from the opening a width of less than approximately 0.2 m.3118. The system of claim 3105, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3119. The system of claim 3105, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3120. The system of claim3105, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3121. The system of claim 3105, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening.
 3122. The system ofclaim 3105, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configured to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 3123. The system of claim3105, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 3124. The system of claim 3105, wherein the system isfurther configured such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 3125. A system configurable to heata coal formation, comprising: at least one elongated member configurableto be disposed in an opening in the formation, wherein at least the oneelongated member is further configurable to provide heat to at least aportion of the formation during use; a conduit configurable to bedisposed in the opening, wherein the conduit is further configurable toprovide an oxidizing fluid from the oxidizing fluid source to a reactionzone in the formation during use, and wherein the system is configurableto allow the oxidizing fluid to oxidize at least some hydrocarbons atthe reaction zone during use such that heat is generated at the reactionzone; and wherein the system is further configurable to allow heat totransfer substantially by conduction from the reaction zone to apyrolysis zone of the formation during use.
 3126. The system of claim3125, wherein the oxidizing fluid is configurable to generate heat inthe reaction zone such that the oxidizing fluid is transported throughthe reaction zone substantially by diffusion.
 3127. The system of claim3125, wherein the conduit comprises orifices, and wherein the orificesare configurable to provide the oxidizing fluid into the opening. 3128.The system of claim 3125, wherein the conduit comprises critical floworifices, and wherein the critical flow orifices are configurable tocontrol a flow of the oxidizing fluid such that a rate of oxidation inthe formation is controlled.
 3129. The system of claim 3125, wherein theconduit is further configurable to be cooled with the oxidizing fluidsuch that the conduit is not substantially heated by oxidation. 3130.The system of claim 3125, wherein the conduit is further configurable toremove an oxidation product.
 3131. The system of claim 3125, wherein theconduit is further configurable to remove an oxidation product such thatthe oxidation product transfers heat to the oxidizing fluid.
 3132. Thesystem of claim 3125, wherein the conduit is further configurable toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 3133. The system of claim 3125,wherein the conduit is further configurable to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.3134. The system of claim 3125, wherein the conduit is furtherconfigurable to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 3135. The system of claim 3125,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 3136. The system ofclaim 3125, further comprising a center conduit disposed within theconduit, wherein center conduit is configurable to provide the oxidizingfluid into the opening during use, and wherein the conduit is furtherconfigurable to remove an oxidation product during use.
 3137. The systemof claim 3125, wherein the portion of the formation extends radiallyfrom the opening a width of less than approximately 0.2 m.
 3138. Thesystem of claim 3125, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation.
 3139. The system of claim 3125, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3140. The system of claim 3125,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3141. Thesystem of claim 3125, further comprising an overburden casing coupled tothe opening, wherein a packing material is disposed at a junction of theoverburden casing and the opening.
 3142. The system of claim 3125,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation,wherein a packing material is disposed at a junction of the overburdencasing and the opening, and wherein the packing material is configurableto substantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 3143. The system of claim 3125, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3144. The system of claim 3125, wherein the system is furtherconfigurable such that transferred heat can pyrolyze at least somehydrocarbons in the pyrolysis zone.
 3145. An in situ method for heatinga coal formation, comprising: heating a portion of the formation to atemperature sufficient to support reaction of hydrocarbons within theportion of the formation with an oxidizing fluid, wherein heatingcomprises applying an electrical current to at least one elongatedmember to provide heat to the portion, and wherein at least the oneelongated member is disposed within the opening; providing the oxidizingfluid to a reaction zone in the formation; allowing the oxidizing fluidto react with at least a portion of the hydrocarbons at the reactionzone to generate heat at the reaction zone; and transferring thegenerated heat substantially by conduction from the reaction zone to apyrolysis zone in the formation.
 3146. The method of claim 3145, furthercomprising transporting the oxidizing fluid through the reaction zone bydiffusion.
 3147. The method of claim 3145, further comprising directingat least a portion of the oxidizing fluid into the opening throughorifices of a conduit disposed in the opening.
 3148. The method of claim3145, further comprising controlling a flow of the oxidizing fluid withcritical flow orifices of a conduit disposed in the opening such that arate of oxidation is controlled.
 3149. The method of claim 3145, furthercomprising increasing a flow of the oxidizing fluid in the opening toaccommodate an increase in a volume of the reaction zone such that arate of oxidation is substantially constant over time within thereaction zone.
 3150. The method of claim 3145, wherein a conduit isdisposed in the opening, the method further comprising cooling theconduit with the oxidizing fluid to reduce heating of the conduit byoxidation.
 3151. The method of claim 3145, wherein a conduit is disposedwithin the opening, the method further comprising removing an oxidationproduct from the formation through the conduit.
 3152. The method ofclaim 3145, wherein a conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the conduit and transferring heat from the oxidation product inthe conduit to the oxidizing fluid in the conduit.
 3153. The method ofclaim 3145, wherein a conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the conduit, wherein a flow rate of the oxidizing fluid in theconduit is approximately equal to a flow rate of the oxidation productin the conduit.
 3154. The method of claim 3145, wherein a conduit isdisposed within the opening, the method further comprising removing anoxidation product from the formation through the conduit and controllinga pressure between the oxidizing fluid and the oxidation product in theconduit to reduce contamination of the oxidation product by theoxidizing fluid.
 3155. The method of claim 3145, wherein a conduit isdisposed within the opening, the method further comprising removing anoxidation product from the formation through the conduit andsubstantially inhibiting the oxidation product from flowing intoportions of the formation beyond the reaction zone.
 3156. The method ofclaim 3145, further comprising substantially inhibiting the oxidizingfluid from flowing into portions of the formation beyond the reactionzone.
 3157. The method of claim 3145, wherein a center conduit isdisposed within an outer conduit, and wherein the outer conduit isdisposed within the opening, the method further comprising providing theoxidizing fluid into the opening through the center conduit and removingan oxidation product through the outer conduit.
 3158. The method ofclaim 3145, wherein the portion of the formation extends radially fromthe opening a width of less than approximately 0.2 m.
 3159. The methodof claim 3145, further comprising removing water from the formationprior to heating the portion.
 3160. The method of claim 3145, furthercomprising controlling the temperature of the formation to substantiallyinhibit production of oxides of nitrogen during oxidation.
 3161. Themethod of claim 3145, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3162. The method of claim 3145, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3163. The method of claim3145, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3164. The method of claim 3145, further comprising coupling anoverburden casing to the opening, wherein a packing material is disposedat a junction of the overburden casing and the opening.
 3165. The methodof claim 3145, wherein the pyrolysis zone is substantially adjacent tothe reaction zone.
 3166. A system configured to heat a coal formation,comprising: a heat exchanger disposed external to the formation, whereinthe heat exchanger is configured to heat an oxidizing fluid during use;a conduit disposed in the opening, wherein the conduit is configured toprovide the heated oxidizing fluid from the heat exchanger to at least aportion of the formation during use, wherein the system is configured toallow heat to transfer from the heated oxidizing fluid to at least theportion of the formation during use, and wherein the oxidizing fluid isselected to oxidize at least some hydrocarbons at a reaction zone in theformation during use such that heat is generated at the reaction zone;and wherein the system is configured to allow heat to transfersubstantially by conduction from the reaction zone to a pyrolysis zoneof the formation during use.
 3167. The system of claim 3166, wherein theoxidizing fluid is configured to generate heat in the reaction zone suchthat the oxidizing fluid is transported through the reaction zonesubstantially by diffusion.
 3168. The system of claim 3166, wherein theconduit comprises orifices, and wherein the orifices are configured toprovide the oxidizing fluid into the opening.
 3169. The system of claim3166, wherein the conduit comprises critical flow orifices, and whereinthe critical flow orifices are configured to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 3170. The system of claim 3166, wherein the conduit isfurther configured to be cooled with the oxidizing fluid such that theconduit is not substantially heated by oxidation.
 3171. The system ofclaim 3166, wherein the conduit is further configured to remove anoxidation product.
 3172. The system of claim 3166, wherein the conduitis further configured to remove an oxidation product, such that theoxidation product transfers heat to the oxidizing fluid.
 3173. Thesystem of claim 3166, wherein the conduit is further configured toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 3174. The system of claim 3166,wherein the conduit is further configured to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.3175. The system of claim 3166, wherein the conduit is furtherconfigured to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 3176. The system of claim 3166,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 3177. The system ofclaim 3166, further comprising a center conduit disposed within theconduit, wherein the center conduit is configured to provide theoxidizing fluid into the opening during use, and wherein the conduit isfurther configured to remove an oxidation product during use.
 3178. Thesystem of claim 3166, wherein the portion of the formation extendsradially from the opening a width of less than approximately 0.2 m.3179. The system of claim 3166, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3180. The system of claim 3166, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3181. The system of claim3166, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3182. The system of claim 3166, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening.
 3183. The system ofclaim 3166, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configured to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 3184. The system of claim3166, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 3185. A system configurable to heat a coal formation,comprising: a heat exchanger configurable to be disposed external to theformation, wherein the heat exchanger is further configurable to heat anoxidizing fluid during use; a conduit configurable to be disposed in theopening, wherein the conduit is further configurable to provide theheated oxidizing fluid from the heat exchanger to at least a portion ofthe formation during use, wherein the system is configurable to allowheat to transfer from the heated oxidizing fluid to at least the portionof the formation during use, and wherein the system is furtherconfigurable to allow the oxidizing fluid to oxidize at least somehydrocarbons at a reaction zone in the formation during use such thatheat is generated at the reaction zone; and wherein the system isfurther configurable to allow heat to transfer substantially byconduction from the reaction zone to a pyrolysis zone of the formationduring use.
 3186. The system of claim 3185, wherein the oxidizing fluidis configurable to generate heat in the reaction zone such that theoxidizing fluid is transported through the reaction zone substantiallyby diffusion.
 3187. The system of claim 3185, wherein the conduitcomprises orifices, and wherein the orifices are configurable to providethe oxidizing fluid into the opening.
 3188. The system of claim 3185,wherein the conduit comprises critical flow orifices, and wherein thecritical flow orifices are configurable to control a flow of theoxidizing fluid such that a rate of oxidation in the formation iscontrolled.
 3189. The system of claim 3185, wherein the conduit isfurther configurable to be cooled with the oxidizing fluid such that theconduit is not substantially heated by oxidation.
 3190. The system ofclaim 3185, wherein the conduit is further configurable to remove anoxidation product.
 3191. The system of claim 3185, wherein the conduitis further configurable to remove an oxidation product such that theoxidation product transfers heat to the oxidizing fluid.
 3192. Thesystem of claim 3185, wherein the conduit is further configurable toremove an oxidation product, and wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 3193. The system of claim 3185,wherein the conduit is further configurable to remove an oxidationproduct, and wherein a pressure of the oxidizing fluid in the conduitand a pressure of the oxidation product in the conduit are controlled toreduce contamination of the oxidation product by the oxidizing fluid.3194. The system of claim 3185, wherein the conduit is furtherconfigurable to remove an oxidation product, and wherein the oxidationproduct is substantially inhibited from flowing into portions of theformation beyond the reaction zone.
 3195. The system of claim 3185,wherein the oxidizing fluid is substantially inhibited from flowing intoportions of the formation beyond the reaction zone.
 3196. The system ofclaim 3185, further comprising a center conduit disposed within theconduit, wherein center conduit is configurable to provide the oxidizingfluid into the opening during use, and wherein the second conduit isfurther configurable to remove an oxidation product during use. 3197.The system of claim 3185, wherein the portion of the formation extendsradially from the opening a width of less than approximately 0.2 m.3198. The system of claim 3185, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3199. The system of claim 3185, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3200. The system of claim3185, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3201. The system of claim 3185, further comprising an overburdencasing coupled to the opening, wherein a packing material is disposed ata junction of the overburden casing and the opening .
 3202. The systemof claim 3185, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configurable to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 3203. The system of claim3185, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 3204. An in situ method for heating a coal formation,comprising: heating a portion of the formation to a temperaturesufficient to support reaction of hydrocarbons within the portion of theformation with an oxidizing fluid, wherein heating comprises: heatingthe oxidizing fluid with a heat exchanger, wherein the heat exchanger isdisposed external to the formation; providing the heated oxidizing fluidfrom the heat exchanger to the portion of the formation; and allowingheat to transfer from the heated oxidizing fluid to the portion of theformation; providing the oxidizing fluid to a reaction zone in theformation; allowing the oxidizing fluid to react with at least a portionof the hydrocarbons at the reaction zone to generate heat at thereaction zone; and transferring the generated heat substantially byconduction from the reaction zone to a pyrolysis zone in the formation.3205. The method of claim 3204, further comprising transporting theoxidizing fluid through the reaction zone by diffusion.
 3206. The methodof claim 3204, further comprising directing at least a portion of theoxidizing fluid into the opening through orifices of a conduit disposedin the opening.
 3207. The method of claim 3204, further comprisingcontrolling a flow of the oxidizing fluid with critical flow orifices ofa conduit disposed in the opening such that a rate of oxidation iscontrolled.
 3208. The method of claim 3204, further comprisingincreasing a flow of the oxidizing fluid in the opening to accommodatean increase in a volume of the reaction zone such that a rate ofoxidation is substantially constant over time within the reaction zone.3209. The method of claim 3204, wherein a conduit is disposed in theopening, the method further comprising cooling the conduit with theoxidizing fluid to reduce heating of the conduit by oxidation.
 3210. Themethod of claim 3204, wherein a conduit is disposed within the opening,the method further comprising removing an oxidation product from theformation through the conduit.
 3211. The method of claim 3204, wherein aconduit is disposed within the opening, the method further comprisingremoving an oxidation product from the formation through the conduit andtransferring heat from the oxidation product in the conduit to theoxidizing fluid in the conduit.
 3212. The method of claim 3204, whereina conduit is disposed within the opening, the method further comprisingremoving an oxidation product from the formation through the conduit,wherein a flow rate of the oxidizing fluid in the conduit isapproximately equal to a flow rate of the oxidation product in theconduit.
 3213. The method of claim 3204, wherein a conduit is disposedwithin the opening, the method further comprising removing an oxidationproduct from the formation through the conduit and controlling apressure between the oxidizing fluid and the oxidation product in theconduit to reduce contamination of the oxidation product by theoxidizing fluid.
 3214. The method of claim 3204, wherein a conduit isdisposed within the opening, the method further comprising removing anoxidation product from the formation through the conduit andsubstantially inhibiting the oxidation product from flowing intoportions of the formation beyond the reaction zone.
 3215. The method ofclaim 3204, further comprising substantially inhibiting the oxidizingfluid from flowing into portions of the formation beyond the reactionzone.
 3216. The method of claim 3204, wherein a center conduit isdisposed within an outer conduit, and wherein the outer conduit isdisposed within the opening, the method further comprising providing theoxidizing fluid into the opening through the center conduit and removingan oxidation product through the outer conduit.
 3217. The method ofclaim 3204, wherein the portion of the formation extends radially fromthe opening a width of less than approximately 0.2 m.
 3218. The methodof claim 3204, further comprising removing water from the formationprior to heating the portion.
 3219. The method of claim 3204, furthercomprising controlling the temperature of the formation to substantiallyinhibit production of oxides of nitrogen during oxidation.
 3220. Themethod of claim 3204, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 3221. The method of claim 3204, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3222. The method of claim3204, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3223. The method of claim 3204, further comprising coupling anoverburden casing to the opening, wherein a packing material is disposedat a junction of the overburden casing and the opening.
 3224. The methodof claim 3204, wherein the pyrolysis zone is substantially adjacent tothe reaction zone.
 3225. An in situ method for heating a coal formation,comprising: heating a portion of the formation to a temperaturesufficient to support reaction of hydrocarbons within the portion of theformation with an oxidizing fluid, wherein heating comprises: oxidizinga fuel gas in a heater, wherein the heater is disposed external to theformation; providing the oxidized fuel gas from the heater to theportion of the formation; and allowing heat to transfer from theoxidized fuel gas to the portion of the formation; providing theoxidizing fluid to a reaction zone in the formation; allowing theoxidizing fluid to react with at least a portion of the hydrocarbons atthe reaction zone to generate heat at the reaction zone; andtransferring the generated heat substantially by conduction from thereaction zone to a pyrolysis zone in the formation.
 3226. The method ofclaim 3225, further comprising transporting the oxidizing fluid throughthe reaction zone by diffusion.
 3227. The method of claim 3225, furthercomprising directing at least a portion of the oxidizing fluid into theopening through orifices of a conduit disposed in the opening.
 3228. Themethod of claim 3225, further comprising controlling a flow of theoxidizing fluid with critical flow orifices of a conduit disposed in theopening such that a rate of oxidation is controlled.
 3229. The method ofclaim 3225, further comprising increasing a flow of the oxidizing fluidin the opening to accommodate an increase in a volume of the reactionzone such that a rate of oxidation is substantially constant over timewithin the reaction zone.
 3230. The method of claim 3225, wherein aconduit is disposed in the opening, the method further comprisingcooling the conduit with the oxidizing fluid to reduce heating of theconduit by oxidation.
 3231. The method of claim 3225, wherein a conduitis disposed within the opening, the method further comprising removingan oxidation product from the formation through the conduit.
 3232. Themethod of claim 3225, wherein a conduit is disposed within the opening,the method further comprising removing an oxidation product from theformation through the conduit and transferring heat from the oxidationproduct in the conduit to the oxidizing fluid in the conduit.
 3233. Themethod of claim 3225, wherein a conduit is disposed within the opening,the method further comprising removing an oxidation product from theformation through the conduit, wherein a flow rate of the oxidizingfluid in the conduit is approximately equal to a flow rate of theoxidation product in the conduit.
 3234. The method of claim 3225,wherein a conduit is disposed within the opening, the method furthercomprising removing an oxidation product from the formation through theconduit and controlling a pressure between the oxidizing fluid and theoxidation product in the conduit to reduce contamination of theoxidation product by the oxidizing fluid.
 3235. The method of claim3225, wherein a conduit is disposed within the opening, the methodfurther comprising removing an oxidation product from the formationthrough the conduit and substantially inhibiting the oxidation productfrom flowing into portions of the formation beyond the reaction zone.3236. The method of claim 3225, further comprising substantiallyinhibiting the oxidizing fluid from flowing into portions of theformation beyond the reaction zone.
 3237. The method of claim 3225,wherein a center conduit is disposed within an outer conduit, andwherein the outer conduit is disposed within the opening, the methodfurther comprising providing the oxidizing fluid into the openingthrough the center conduit and removing an oxidation product through theouter conduit.
 3238. The method of claim 3225, wherein the portion ofthe formation extends radially from the opening a width of less thanapproximately 0.2 m.
 3239. The method of claim 3225, further comprisingremoving water from the formation prior to heating the portion. 3240.The method of claim 3225, further comprising controlling the temperatureof the formation to substantially inhibit production of oxides ofnitrogen during oxidation.
 3241. The method of claim 3225, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3242.The method of claim 3225, further comprising coupling an overburdencasing to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3243. The method of claim 3225, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing is further disposed in cement.
 3244. The method of claim 3225,further comprising coupling an overburden casing to the opening, whereina packing material is disposed at a junction of the overburden casingand the opening.
 3245. The method of claim 3225, wherein the pyrolysiszone is substantially adjacent to the reaction zone.
 3246. A systemconfigured to heat a coal formation, comprising: an insulated conductordisposed within an open wellbore in the formation, wherein the insulatedconductor is configured to provide radiant heat to at least a portion ofthe formation during use; and wherein the system is configured to allowheat to transfer from the insulated conductor to a selected section ofthe formation during use.
 3247. The system of claim 3246, wherein theinsulated conductor is further configured to generate heat duringapplication of an electrical current to the insulated conductor duringuse.
 3248. The system of claim 3246, further comprising a supportmember, wherein the support member is configured to support theinsulated conductor.
 3249. The system of claim 3246, further comprisinga support member and a centralizer, wherein the support member isconfigured to support the insulated conductor, and wherein thecentralizer is configured to maintain a location of the insulatedconductor on the support member.
 3250. The system of claim 3246, whereinthe open wellbore comprises a diameter of at least approximately 5 cm.3251. The system of claim 3246, further comprising a lead-in conductorcoupled to the insulated conductor, wherein the lead-in conductorcomprises a low resistance conductor configured to generatesubstantially no heat.
 3252. The system of claim 3246, furthercomprising a lead-in conductor coupled to the insulated conductor,wherein the lead-in conductor comprises a rubber insulated conductor.3253. The system of claim 3246, further comprising a lead-in conductorcoupled to the insulated conductor, wherein the lead-in conductorcomprises a copper wire.
 3254. The system of claim 3246, furthercomprising a lead-in conductor coupled to the insulated conductor with acold pin transition conductor.
 3255. The system of claim 3246, furthercomprising a lead-in conductor coupled to the insulated conductor with acold pin transition conductor, where in the cold pin transitionconductor comprises a substantially low resistance insulated conductor.3256. The system of claim 3246, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,and wherein the electrically insulating material is disposed in asheath.
 3257. The system of claim 3246, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,and wherein the conductor comprises a copper-nickel alloy.
 3258. Thesystem of claim 3246, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, wherein theconductor comprises a copper-nickel alloy, and wherein the copper-nickelalloy comprises approximately 7% nickel by weight to approximately 12%nickel by weight.
 3259. The system of claim 3246, wherein the insulatedconductor comprises a conductor disposed in an electrically insulatingmaterial, wherein the conductor comprises a copper-nickel alloy, andwherein the copper-nickel alloy comprises approximately 2% nickel byweight to approximately 6% nickel by weight.
 3260. The system of claim3246, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, and wherein the electricallyinsulating material comprises a thermally conductive material.
 3261. Thesystem of claim 3246, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material comprises magnesium oxide. 3262.The system of claim 3246, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, wherein theelectrically insulating material comprises magnesium oxide, and whereinthe magnesium oxide comprises a thickness of at least approximately 1mm.
 3263. The system of claim 3246, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,and wherein the electrically insulating material comprises aluminumoxide and magnesium oxide.
 3264. The system of claim 3246, wherein theinsulated conductor comprises a conductor disposed in an electricallyinsulating material, wherein the electrically insulating materialcomprises magnesium oxide, wherein the magnesium oxide comprises grainparticles, and wherein the grain particles are configured to occupyporous spaces within the magnesium oxide.
 3265. The system of claim3246, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, and wherein the electricallyinsulating material is disposed in a sheath, and wherein the sheathcomprises a corrosion-resistant material.
 3266. The system of claim3246, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, and wherein the electricallyinsulating material is disposed in a sheath, and wherein the sheathcomprises stainless steel.
 3267. The system of claim 3246, furthercomprising two additional insulated conductors, wherein the insulatedconductor and the two additional insulated conductors are configured ina 3-phase Y configuration.
 3268. The system of claim 3246, furthercomprising an additional insulated conductor, wherein the insulatedconductor and the additional insulated conductor are coupled to asupport member, and wherein the insulated conductor and the additionalinsulated conductor are configured in a series electrical configuration.3269. The system of claim 3246, further comprising an additionalinsulated conductor, wherein the insulated conductor and the additionalinsulated conductor are coupled to a support member, and wherein theinsulated conductor and the additional insulated conductor areconfigured in a parallel electrical configuration.
 3270. The system ofclaim 3246, wherein the insulated conductor is configured to generateradiant heat of approximately 500 W/m to approximately 1150 W/m duringuse.
 3271. The system of claim 3246, further comprising a support memberconfigured to support the insulated conductor, wherein the supportmember comprises orifices configured to provide fluid flow through thesupport member into the open wellbore during use.
 3272. The system ofclaim 3246, further comprising a support member configured to supportthe insulated conductor, wherein the support member comprises criticalflow orifices configured to provide a substantially constant amount offluid flow through the support member into the open wellbore during use.3273. The system of claim 3246, further comprising a tube coupled to theinsulated conductor, wherein the tube is configured to provide a flow offluid into the open wellbore during use.
 3274. The system of claim 3246,further comprising a tube coupled to the insulated conductor, whereinthe tube comprises critical flow orifices configured to provide asubstantially constant amount of fluid flow through the support memberinto the open wellbore during use.
 3275. The system of claim 3246,further comprising an overburden casing coupled to the open wellbore,wherein the overburden casing is disposed in an overburden of theformation.
 3276. The system of claim 3246, further comprising anoverburden casing coupled to the open wellbore, wherein the overburdencasing is disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3277. The system of claim 3246,further comprising an overburden casing coupled to the open wellbore,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing is further disposed incement.
 3278. The system of claim 3246, further comprising an overburdencasing coupled to the open wellbore, wherein the overburden casing isdisposed in an overburden of the formation, and wherein a packingmaterial is disposed at a junction of the overburden casing and the openwellbore.
 3279. The system of claim 3246, further comprising anoverburden casing coupled to the open wellbore, wherein the overburdencasing is disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and the openwellbore, and wherein the packing material is configured tosubstantially inhibit a flow of fluid between the open wellbore and theoverburden casing during use.
 3280. The system of claim 3246, furthercomprising an overburden casing coupled to the open wellbore, whereinthe overburden casing is disposed in an overburden of the formation,wherein a packing material is disposed at a junction of the overburdencasing and the open wellbore, and wherein the packing material comprisescement.
 3281. The system of claim 3246, further comprising an overburdencasing coupled to the open wellbore, wherein the overburden casing isdisposed in an overburden of the formation, the system furthercomprising a wellhead coupled to the overburden casing and a lead-inconductor coupled to the insulated conductor, wherein the wellhead isdisposed external to the overburden, wherein the wellhead comprises atleast one sealing flange, and wherein at least the one sealing flange isconfigured to couple to the lead-in conductor.
 3282. The system of claim3246, wherein the system is further configured to transfer heat suchthat the transferred heat can pyrolyze at least some of the hydrocarbonsin the selected section.
 3283. A system configurable to heat a coalformation, comprising: an insulated conductor configurable to bedisposed within an open wellbore in the formation, wherein the insulatedconductor is further configurable to provide radiant heat to at least aportion of the formation during use; and wherein the system isconfigurable to allow heat to transfer from the insulated conductor to aselected section of the formation during use.
 3284. The system of claim3283, wherein the insulated conductor is firer configurable to generateheat during application of an electrical current to the insulatedconductor during use.
 3285. The system of claim 3283, further comprisinga support member, wherein the support member is configurable to supportthe insulated conductor.
 3286. The system of claim 3283, furthercomprising a support member and a centralizer, wherein the supportmember is configurable to support the insulated conductor, and whereinthe centralizer is configurable to maintain a location of the insulatedconductor on the support member.
 3287. The system of claim 3283, whereinthe open wellbore comprises a diameter of at least approximately 5 cm.3288. The system of claim 3283, further comprising a lead-in conductorcoupled to the insulated conductor, wherein the lead-in conductorcomprises a low resistance conductor configurable to generatesubstantially no heat.
 3289. The system of claim 3283, furthercomprising a lead-in conductor coupled to the insulated conductor,wherein the lead-in conductor comprises a rubber insulated conductor.3290. The system of claim 3283, further comprising a lead-in conductorcoupled to the insulated conductor, wherein the lead-in conductorcomprises a copper wire.
 3291. The system of claim 3283, furthercomprising a lead-in conductor coupled to the insulated conductor with acold pin transition conductor.
 3292. The system of claim 3283, furthercomprising a lead-in conductor coupled to the insulated conductor with acold pin transition conductor, wherein the cold pin transition conductorcomprises a substantially low resistance insulated conductor.
 3293. Thesystem of claim 3283, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material is disposed in a sheath.
 3294. Thesystem of claim 3283, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, and whereinthe conductor comprises a copper-nickel alloy.
 3295. The system of claim3283, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, wherein the conductor comprises acopper-nickel alloy, and wherein the copper-nickel alloy comprisesapproximately 7% nickel by weight to approximately 12% nickel by weight.3296. The system of claim 3283, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,wherein the conductor comprises a copper-nickel alloy, and wherein thecopper-nickel alloy comprises approximately 2% nickel by weight toapproximately 6% nickel by weight.
 3297. The system of claim 3283,wherein the insulated conductor comprises a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material comprises a thermally conductive material.
 3298. Thesystem of claim 3283, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material comprises magnesium oxide. 3299.The system of claim 3283, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, wherein theelectrically insulating material comprises magnesium oxide, and whereinthe magnesium oxide comprises a thickness of at least approximately 1mm.
 3300. The system of claim 3283, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,and wherein the electrically insulating material comprises aluminumoxide and magnesium oxide.
 3301. The system of claim 3283, wherein theinsulated conductor comprises a conductor disposed in an electricallyinsulating materials wherein the electrically insulating materialcomprises magnesium oxide, wherein the magnesium oxide comprises grainparticles, and wherein the grain particles are configurable to occupyporous spaces within the magnesium oxide.
 3302. The system of claim3283, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, and wherein the electricallyinsulating material is disposed in a sheath, and wherein the sheathcomprises a corrosion-resistant material.
 3303. The system of claim3283, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, and wherein the electricallyinsulating material is disposed in a sheath, and wherein the sheathcomprises stainless steel.
 3304. The system of claim 3283, furthercomprising two additional insulated conductors, wherein the insulatedconductor and the two additional insulated conductors are configurablein a 3-phase Y configuration.
 3305. The system of claim 3283, furthercomprising an additional insulated conductor, wherein the insulatedconductor and the additional insulated conductor are coupled to asupport member, and wherein the insulated conductor and the additionalinsulated conductor are configurable in a series electricalconfiguration.
 3306. The system of claim 3283, further comprising anadditional insulated conductor, wherein the insulated conductor and theadditional insulated conductor are coupled to a support member, andwherein the insulated conductor and the additional insulated conductorare configurable in a parallel electrical configuration.
 3307. Thesystem of claim 3283, wherein the insulated conductor is configurable togenerate radiant heat of approximately 500 W/m to approximately 1150 W/mduring use.
 3308. The system of claim 3283, further comprising a supportmember configurable to support the insulated conductor, wherein thesupport member comprises orifices configurable to provide fluid flowthrough the support member into the open wellbore during use.
 3309. Thesystem of claim 3283, further comprising a support member configurableto support the insulated conductor, wherein the support member comprisescritical flow orifices configurable to provide a substantially constantamount of fluid flow through the support member into the open wellboreduring use.
 3310. The system of claim 3283, further comprising a tubecoupled to the insulated conductor, wherein the tube is configurable toprovide a flow of fluid into the open wellbore during use.
 3311. Thesystem of claim 3283, further comprising a tube coupled to the firstinsulated conductor, wherein the tube comprises critical flow orificesconfigurable to provide a substantially constant amount of fluid flowthrough the support member into the open wellbore during use.
 3312. Thesystem of claim 3283, further comprising an overburden casing coupled tothe open wellbore, wherein the overburden casing is disposed in anoverburden of the formation.
 3313. The system of claim 3283, furthercomprising an overburden casing coupled to the open wellbore, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing comprises steel.
 3314. The system of claim3283, further comprising an overburden casing coupled to the openwellbore, wherein the overburden casing is disposed in an overburden ofthe formation, and wherein the overburden casing is further disposed incement.
 3315. The system of claim 3283, further comprising an overburdencasing coupled to the open wellbore, wherein the overburden casing isdisposed in an overburden of the formation, and wherein a packingmaterial is disposed at a junction of the overburden casing and the openwellbore.
 3316. The system of claim 3283, further comprising anoverburden casing coupled to the open wellbore, wherein the overburdencasing is disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of the overburden casing and the openwellbore, and wherein the packing material is configurable tosubstantially inhibit a flow of fluid between the open wellbore and theoverburden casing during use.
 3317. The system of claim 3283, furthercomprising an overburden casing coupled to the open wellbore, whereinthe overburden casing is disposed in an overburden of the formation,wherein a packing material is disposed at a junction of the overburdencasing and the open wellbore, and wherein the packing material comprisescement.
 3318. The system of claim 3283, further comprising an overburdencasing coupled to the open wellbore, wherein the overburden casing isdisposed in an overburden of the formation, the system furthercomprising a wellhead coupled to the overburden casing and a lead-inconductor coupled to the insulated conductor, wherein the wellhead isdisposed external to the overburden, wherein the wellhead comprises atleast one sealing flange, and wherein at least the one sealing flange isconfigurable to couple to the lead-in conductor.
 3319. The system ofclaim 3283, wherein the system is further configured to transfer heatsuch that the transferred heat can pyrolyze at least some hydrocarbonsin the selected section.
 3320. An in situ method for heating a coalformation, comprising: applying an electrical current to an insulatedconductor to provide radiant heat to at least a portion of theformation, wherein the insulated conductor is disposed within an openwellbore in the formation; and allowing the radiant heat to transferfrom the insulated conductor to a selected section of the formation.3321. The method of claim 3320, further comprising supporting theinsulated conductor on a support member.
 3322. The method of claim 3320,further comprising supporting the insulated conductor on a supportmember and maintaining a location of the insulated conductor on thesupport member with a centralizer.
 3323. The method of claim 3320,wherein the insulated conductor is coupled to two additional insulatedconductors, wherein the insulated conductor and the two insulatedconductors are disposed within the open wellbore, and wherein the threeinsulated conductors are electrically coupled in a 3-phase Yconfiguration.
 3324. The method of claim 3320, wherein an additionalinsulated conductor is disposed within the open wellbore.
 3325. Themethod of claim 3320, wherein an additional insulated conductor isdisposed within the open wellbore, and wherein the insulated conductorand the additional insulated conductor are electrically coupled in aseries configuration.
 3326. The method of claim 3320, wherein anadditional insulated conductor is disposed within the open wellbore, andwherein the insulated conductor and the additional insulated conductorare electrically coupled in a parallel configuration.
 3327. The methodof claim 3320, wherein the provided heat comprises approximately 500 W/mto approximately 1150 W/m.
 3328. The method of claim 3320, wherein theinsulated conductor comprises a conductor disposed in an electricallyinsulating material, and wherein the conductor comprises a copper-nickelalloy.
 3329. The method of claim 3320, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,wherein the conductor comprises a copper-nickel alloy, and wherein thecopper-nickel alloy comprises approximately 7% nickel by weigh-t toapproximately 12% nickel by weight.
 3330. The method of claim 3320,wherein the insulated conductor comprises a conductor disposed in anelectrically insulating material, wherein the conductor comprises acopper-nickel alloy, and wherein the copper-nickel alloy comprisesapproximately 2% nickel by weight to approximately 6% nickel by weight.3331. The method of claim 3320, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,and wherein the electrically insulating material comprises magnesiumoxide.
 3332. The method of claim 3320, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,wherein the electrically insulating material comprises magnesium oxide,and wherein the magnesium oxide comprises a thickness of at leastapproximately 1 mm.
 3333. The method of claim 3320, wherein theinsulated conductor comprises a conductor disposed in an electricallyinsulating material, and wherein the electrically insulating materialcomprises aluminum oxide and magnesium oxide.
 3334. The method of claim3320, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, wherein the electrically insulatingmaterial comprises magnesium oxide, wherein the magnesium oxidecomprises grain particles, and wherein the grain particles areconfigured to occupy porous spaces within the magnesium oxide.
 3335. Themethod of claim 3320, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, wherein theinsulating material is disposed in a sheath, and wherein the sheathcomprises a corrosion-resistant material.
 3336. The method of claim3320, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, wherein the insulating material isdisposed in a sheath, and wherein the sheath comprises stainless steel.3337. The method of claim 3320, further comprising supporting theinsulated conductor on a support member and flowing a fluid into theopen wellbore through an orifice in the support member.
 3338. The methodof claim 3320, further comprising supporting the insulated conductor ona support member and flowing a substantially constant amount of fluidinto the open wellbore through critical flow orifices in the supportmember.
 3339. The method of claim 3320, wherein a perforated tube isdisposed in the open wellbore proximate to the insulated conductor, themethod further comprising flowing a fluid into the open wellbore throughthe perforated tube.
 3340. The method of claim 3320, wherein a tube isdisposed in the open wellbore proximate to the insulated conductor, themethod further comprising flowing a substantially constant amount afluid into the open wellbore through critical flow orifices in the tube.3341. The method of claim 3320, further comprising supporting theinsulated conductor on a support member and flowing a corrosioninhibiting fluid into the open wellbore through an orifice in thesupport member.
 3342. The method of claim 3320, wherein a perforatedtube is disposed in the open wellbore proximate to the insulatedconductor, the method further comprising flowing a corrosion inhibitingfluid into the open wellbore through the perforated tube.
 3343. Themethod of claim 3320, further comprising determining a temperaturedistribution in the insulated conductor using an electromagnetic signalprovided to the insulated conductor.
 3344. The method of claim 3320,further comprising monitoring a leakage current of the insulatedconductor.
 3345. The method of claim 3320, further comprising monitoringthe applied electrical current.
 3346. The method of claim 3320, furthercomprising monitoring a voltage applied to the insulated conductor.3347. The method of claim 3320, further comprising monitoring atemperature in the insulated conductor with at least one thermocouple.3348. The method of claim 3320, further comprising electrically couplinga lead-in conductor to the insulated conductor, wherein the lead-inconductor comprises a low resistance conductor configured to generatesubstantially no heat.
 3349. The method of claim 3320, furthercomprising electrically coupling a lead-in conductor to the insulatedconductor using a cold pin transition conductor.
 3350. The method ofclaim 3320, further comprising electrically coupling a lead-in conductorto the insulated conductor using a cold pin transition conductor,wherein the cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 3351. The method of claim 3320, furthercomprising coupling an overburden casing to the open wellbore, whereinthe overburden casing is disposed in an overburden of the formation.3352. The method of claim 3320, further comprising coupling anoverburden casing to the open wellbore, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing comprises steel.
 3353. The method of claim 3320, furthercomprising coupling an overburden casing to the open wellbore, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3354. Themethod of claim 3320, further comprising coupling an overburden casingto the open wellbore, wherein the overburden casing is disposed in anoverburden of the formation, and wherein a packing material is disposedat a junction of the overburden casing and the open wellbore.
 3355. Themethod of claim 3320, further comprising coupling an overburden casingto the open wellbore, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the method further comprisesinhibiting a flow of fluid between the open wellbore and the overburdencasing with a packing material.
 3356. The method of claim 3320, furthercomprising heating at least the portion of the formation to pyrolyze atleast some hydrocarbons within the formation.
 3357. An in situ methodfor heating a coal formation, comprising: applying an electrical currentto an insulated conductor to provide heat to at least a portion of theformation, wherein the insulated conductor is disposed within an openingin the formation; and allowing the heat to transfer from the insulatedconductor to a section of the formation.
 3358. The method of claim 3357,further comprising supporting the insulated conductor on a supportmember.
 3359. The method of claim 3357, further comprising supportingthe insulated conductor on a support member and maintaining a locationof the first insulated conductor on the support member with acentralizer.
 3360. The method of claim 3357, where in the insulatedconductor is coupled to two additional insulated conductors, wherein theinsulated conductor and the two insulated conductors are disposed withinthe opening, and wherein the three insulated conductors are electricallycoupled in a 3-phase Y configuration.
 3361. The method of claim 3357,wherein an additional insulated conductor is disposed within theopening.
 3362. The method of claim 3357, wherein an additional insulatedconductor is disposed within the opening, and wherein the insulatedconductor and the additional insulated conductor are electricallycoupled in a series configuration.
 3363. The method of claim 3357,wherein an additional insulated conductor is disposed within theopening, and wherein the insulated conductor and the additionalinsulated conductor are electrically coupled in a parallelconfiguration.
 3364. The method of claim 3357, wherein the provided heatcomprises approximately 500 W/m to approximately 1150 W/m.
 3365. Themethod of claim 3357, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, and whereinthe conductor comprises a copper-nickel alloy.
 3366. The method of claim3357, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, wherein the conductor comprises acopper-nickel alloy, and wherein the copper-nickel alloy comprisesapproximately 7% nickel by weight to approximately 12% nickel by weight.3367. The method of claim 3357, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,wherein the conductor comprises a copper-nickel alloy, and wherein thecopper-nickel alloy comprises approximately 2% nickel by weight toapproximately 6% nickel by weight.
 3368. The method of claim 3357,wherein the insulated conductor comprises a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material comprises magnesium oxide.
 3369. The method of claim3357, wherein the insulated conductor comprises a conductor disposed inan electrically insulating material, wherein the electrically insulatingmaterial comprises magnesium oxide, and wherein the magnesium oxidecomprises a thickness of at least approximately 1 mm.
 3370. The methodof claim 3357, wherein the insulated conductor comprises a conductordisposed in an electrically insulating material, and wherein theelectrically insulating material comprises aluminum oxide and magnesiumoxide.
 3371. The method of claim 3357, wherein the insulated conductorcomprises a conductor disposed in an electrically insulating material,wherein the electrically insulating material comprises magnesium oxide,wherein the magnesium oxide comprises grain particles, and wherein thegrain particles are configured to occupy porous spaces within themagnesium oxide.
 3372. The method of claim 3357, wherein the insulatedconductor comprises a conductor disposed in an electrically insulatingmaterial, wherein the insulating material is disposed in a sheath, andwherein the sheath comprises a corrosion-resistant material.
 3373. Themethod of claim 3357, wherein the insulated conductor comprises aconductor disposed in an electrically insulating material, wherein theinsulating material is disposed in a sheath, and wherein the sheathcomprises stainless steel.
 3374. The method of claim 3357, furthercomprising supporting the insulated conductor on a support member andflowing a fluid into the opening through an orifice in the supportmember.
 3375. The method of claim 3357, further comprising supportingthe insulated conductor on a support member and flowing a substantiallyconstant amount of fluid into the opening through critical flow orificesin the support member.
 3376. The method of claim 3357, wherein aperforated tube is disposed in the opening proximate to the insulatedconductor, the method further comprising flowing a fluid into theopening through the perforated tube.
 3377. The method of claim 3357,wherein a tube is disposed in the opening proximate to the insulatedconductor, the method further comprising flowing a substantiallyconstant amount a fluid into the opening through critical flow orificesin the tube.
 3378. The method of claim 3357, further comprisingsupporting the insulated conductor on a support member and flowing acorrosion inhibiting fluid into the opening through an orifice in thesupport member.
 3379. The method of claim 3357, wherein a perforatedtube is disposed in the opening proximate to the insulated conductor,the method further comprising flowing a corrosion inhibiting fluid intothe opening through the perforated tube.
 3380. The method of claim 3357,further comprising determining a temperature distribution in theinsulated conductor using an electromagnetic signal provided to theinsulated conductor.
 3381. The method of claim 3357, further comprisingmonitoring a leakage current of the insulated conductor.
 3382. Themethod of claim 3357, further comprising monitoring the appliedelectrical current.
 3383. The method of claim 3357, further comprisingmonitoring a voltage applied to the insulated conductor.
 3384. Themethod of claim 3357, further comprising monitoring a temperature in theinsulated conductor with at least one thermocouple.
 3385. The method ofclaim 3357, further comprising electrically coupling a lead-in conductorto the insulated conductor, wherein the lead-in conductor comprises alow resistance conductor configured to generate substantially no heat.3386. The method of claim 3357, further comprising electrically couplinga lead-in conductor to the insulated conductor using a cold pintransition conductor.
 3387. The method of claim 3357, further comprisingelectrically coupling a lead-in conductor to the insulated conductorusing a cold pin transition conductor, wherein the cold pin transitionconductor comprises a substantially low resistance insulated conductor.3388. The method of claim 3357, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation.
 3389. The method of claim3357, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing comprises steel.
 3390. Themethod of claim 3357, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3391. The method of claim 3357, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3392. The method of claim 3357, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the method further comprises inhibiting a flow of fluid betweenthe opening and the overburden casing with a packing material.
 3393. Themethod of claim 3357, further comprising heating at least the portion ofthe formation to substantially pyrolyze at least some hydrocarbonswithin the formation.
 3394. A system configured to heat a coalformation, comprising: an insulated conductor disposed within an openingin the formation, wherein the insulated conductor is configured toprovide heat to at least a portion of the formation during use, whereinthe insulated conductor comprises a copper-nickel alloy, and wherein thecopper-nickel alloy comprises approximately 7% nickel by weight toapproximately 12% nickel by weight; and wherein the system is configuredto allow heat to transfer from the insulated conductor to a selectedsection of the formation during use.
 3395. The system of claim 3394,wherein the insulated conductor is further configured to generate heatduring application of an electrical current to the insulated conductorduring use.
 3396. The system of claim 3394, further comprising a supportmember, wherein the support member is configured to support theinsulated conductor.
 3397. The system of claim 3394, further comprisinga support member and a centralizer, wherein the support member isconfigured to support the insulated conductor, and wherein thecentralizer is configured to maintain a location of the insulatedconductor on the support member.
 3398. The system of claim 3394, whereinthe opening comprises a diameter of at least approximately 5 cm. 3399.The system of claim 3394, further comprising a lead-in conductor coupledto the insulated conductor, wherein the lead-in conductor comprises alow resistance conductor configured to generate substantially no heat.3400. The system of claim 3394, further comprising a lead-in conductorcoupled to the insulated conductor, wherein the lead-in conductorcomprises a rubber insulated conductor.
 3401. The system of claim 3394,further comprising a lead-in conductor coupled to the insulatedconductor, wherein the lead-in conductor comprises a copper wire. 3402.The system of claim 3394, further comprising a lead-in conductor coupledto the insulated conductor with a cold pin transition conductor. 3403.The system of claim 3394, further comprising a lead-in conductor coupledto the insulated conductor with a cold pin transition conductor, whereinthe cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 3404. The system of claim 3394, whereinthe copper-nickel alloy is disposed in an electrically insulatingmaterial, and wherein the electrically insulating material comprises athermally conductive material.
 3405. The system of claim 3394, whereinthe copper-nickel alloy is disposed in an electrically insulatingmaterial, and wherein the electrically insulating material comprisesmagnesium oxide.
 3406. The system of claim 3394, wherein thecopper-nickel alloy is disposed in an electrically insulating material,wherein the electrically insulating material comprises magnesium oxide,and wherein the magnesium oxide comprises a thickness of at leastapproximately 1 mm.
 3407. The system of claim 3394, wherein thecopper-nickel alloy is disposed in an electrically insulating material,and wherein the electrically insulating material comprises aluminumoxide and magnesium oxide.
 3408. The system of claim 3394, wherein thecopper-nickel alloy is disposed in an electrically insulating material,wherein the electrically insulating material comprises magnesium oxide,wherein the magnesium oxide comprises grain particles, and wherein thegrain particles are configured to occupy porous spaces within themagnesium oxide.
 3409. The system of claim 3394, wherein thecopper-nickel alloy is disposed in an electrically insulating material,wherein the electrically insulating material is disposed in a sheath,and wherein the sheath comprises a corrosion-resistant material. 3410.The system of claim 3394, wherein the copper-nickel alloy is disposed inan electrically insulating material, wherein the electrically insulatingmaterial is disposed in a sheath, and wherein the sheath comprisesstainless steel.
 3411. The system of claim 3394, further comprising twoadditional insulated conductors, wherein the insulated conductor and thetwo additional insulated conductors are configured in a 3-phase Yconfiguration.
 3412. The system of claim 3394, further comprising anadditional insulated conductor, wherein the insulated conductor and theadditional insulated conductor are coupled to a support member, andwherein the insulated conductor and the additional insulated conductorare configured in a series electrical configuration.
 3413. The system ofclaim 3394, further comprising an additional insulated conductor,wherein the insulated conductor and the additional insulated conductorare coupled to a support member, and wherein the insulated conductor andthe additional insulated conductor are configured in a parallelelectrical configuration.
 3414. The system of claim 3394, wherein theinsulated conductor is configured to generate radiant heat ofapproximately 500 W/m to approximately 1150 W/m during use.
 3415. Thesystem of claim 3394, further comprising a support member configured tosupport the insulated conductor, wherein the support member comprisesorifices configured to provide fluid flow through the support memberinto the opening during use.
 3416. The system of claim 3394, furthercomprising a support member configured to support the insulatedconductor, wherein the support member comprises critical flow orificesconfigured to provide a substantially constant amount of fluid flowthrough the support member into the opening during use.
 3417. The systemof claim 3394, further comprising a tube coupled to the insulatedconductor, wherein the tube is configured to provide a flow of fluidinto the opening during use.
 3418. The system of claim 3394, furthercomprising a tube coupled to the insulated conductor, wherein the tubecomprises critical flow orifices configured to provide a substantiallyconstant amount of fluid flow through the support member into theopening during use.
 3419. The system of claim 3394, further comprisingan overburden casing coupled to the opening, wherein the overburdencasing is disposed in an overburden of the formation.
 3420. The systemof claim 3394, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, and wherein the overburden casing comprises steel. 3421.The system of claim 3394, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3422. The system of claim 3394, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3423. The system of claim 3394, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material is configured tosubstantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 3424. The system of claim 3394, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3425. The system of claim 3394, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, the system further comprising a wellheadcoupled to the overburden casing and a lead-in conductor coupled to theinsulated conductor, wherein the wellhead is disposed external to theoverburden, wherein the wellhead comprises at least one sealing flange,and wherein at least the one sealing flange is configured to couple tothe lead-in conductor.
 3426. The system of claim 3394, wherein thesystem is further configured to transfer heat such that the transferredheat can pyrolyze at least some hydrocarbons in the selected section.3427. A system configurable to heat a coal formation, comprising: aninsulated conductor configurable to be disposed within an opening in theformation, wherein the insulated conductor is further configurable toprovide heat to at least a portion of the formation during use, whereinthe insulated conductor comprises a copper-nickel alloy, and wherein thecopper-nickel alloy comprises approximately 7% nickel by weight toapproximately 12% nickel by weight; wherein the system is configurableto allow heat to transfer from the insulated conductor to a selectedsection of the formation during use.
 3428. The system of claim 3427,wherein the insulated conductor is further configurable to generate heatduring application of an electrical current to the insulated conductorduring use.
 3429. The system of claim 3427, further comprising a supportmember, wherein the support member is configurable to support theinsulated conductor.
 3430. The system of claim 3427, further comprisinga support member and a centralizer, wherein the support member isconfigurable to support the insulated conductor, and wherein thecentralizer is configurable to maintain a location of the insulatedconductor on the support member.
 3431. The system of claim 3427, whereinthe opening comprises a diameter of at least approximately 5 cm. 3432.The system of claim 3427, further comprising a lead-in conductor coupledto the insulated conductor, wherein the lead-in conductor comprises alow resistance conductor configurable to generate substantially no heat.3433. The system of claim 3427, further comprising a lead-in conductorcoupled to the insulated conductor, wherein the lead-in conductorcomprises a rubber insulated conductor.
 3434. The system of claim 3427,further comprising a lead-in conductor coupled to the insulatedconductor, wherein the lead-in conductor comprises a copper wire. 3435.The system of claim 3427, further comprising a lead-in conductor coupledto the insulated conductor with a cold pin transition conductor. 3436.The system of claim 3427, further comprising a lead-in conductor coupledto the insulated conductor with a cold pin transition conductor, whereinthe cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 3437. The system of claim 3427, whereinthe copper-nickel alloy is disposed in an electrically insulatingmaterial, and wherein the electrically insulating material comprises athermally conductive material.
 3438. The system of claim 3427, whereinthe copper-nickel alloy is disposed in an electrically insulatingmaterial, and wherein the electrically insulating material comprisesmagnesium oxide.
 3439. The system of claim 3 427, wherein thecopper-nickel alloy is disposed in an electrically insulating material,wherein the electrically insulating material comprises magnesium oxide,and wherein the magnesium oxide comprises a thickness of at leastapproximately 1 mm.
 3440. The system of claim 3427, wherein thecopper-nickel alloy is disposed in an electrically insulating material,and wherein the electrically insulating material comprises aluminumoxide and magnesium oxide.
 3441. The system of claim 3427, wherein thecopper-nickel alloy is disposed in an electrically insulating material,wherein the electrically insulating material comprises magnesium oxide,wherein the magnesium oxide comprises grain particles, and wherein thegrain particles are configurable to occupy porous spaces within themagnesium oxide.
 3442. The system of claim 3427, wherein thecopper-nickel alloy is disposed in an electrically insulating material,wherein the electrically insulating material is disposed in a sheath,and wherein the sheath comprises a corrosion-resistant material. 3443.The system of claim 3427, wherein the copper-nickel alloy is disposed inan electrically insulating material, wherein the electrically insulatingmaterial is disposed in a sheath, and wherein the sheath comprisesstainless steel.
 3444. The system of claim 3427, further comprising twoadditional insulated conductors, wherein the insulated conductor and thetwo additional insulated conductors are configurable in a 3-phase Yconfiguration.
 3445. The system of claim 3427, further comprising anadditional insulated conductor, wherein the insulated conductor and theadditional insulated conductor are coupled to a support member, andwherein the insulated conductor and the additional insulated conductorare configurable in a series electrical configuration.
 3446. The systemof claim 3427, further comprising an additional insulated conductor,wherein the insulated conductor and the additional insulated conductorare coupled to a support member, and wherein the insulated conductor andthe additional insulated conductor are configurable in a parallelelectrical configuration.
 3447. The system of claim 3427, wherein theinsulated conductor is configurable to generate radiant heat ofapproximately 500 W/m to approximately 1150 W/m during use.
 3448. Thesystem of claim 3427, further comprising a support member configurableto support the insulated conductor, wherein the support member comprisesorifices configurable to provide fluid flow through the support memberinto the open wellbore during use.
 3449. The system of claim 3427,further comprising a support member configurable to, support theinsulated conductor, wherein the support member comprises critical floworifices configurable to provide a substantially constant amount offluid flow through the support member into the opening during use. 3450.The system of claim 3427, further comprising a tube coupled to theinsulated conductor, wherein the tube is configurable to provide a flowof fluid into the opening during use.
 3451. The system of claim 3427,further comprising a tube coupled to the insulated conductor, whereinthe tube comprises critical flow orifices configurable to provide asubstantially constant amount of fluid flow through the support memberinto the opening during use.
 3452. The system of claim 3427, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3453 .The system of claim 3427, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3454. The system of claim 3427, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3455. The system of claim 3427, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3456. The system of claim 3427, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material is configurable tosubstantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 3457. The system of claim 3427, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3458. The system of claim 3427, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, the system further comprising a wellheadcoupled to the overburden casing and a lead-in conductor coupled to theinsulated conductor, wherein the wellhead is disposed external to theoverburden, wherein the wellhead comprises at least one sealing flange,and wherein at least the one sealing flange is configurable to couple tothe lead-in conductor.
 3459. The system of claim 3427, wherein thesystem is further configured to transfer heat such that the transferredheat can pyrolyze at least some hydrocarbons in the selected section.3460. An in situ method for heating a coal formation, comprising:applying an electrical current to an insulated conductor to provide heatto at least a portion of the formation, wherein the insulated conductoris disposed within an opening in the formation, and wherein theinsulated conductor comprises a copper-nickel alloy of approximately 7%nickel by weight to approximately 12% nickel by weight; and allowing theheat to transfer from the insulated conductor to a selected section ofthe formation.
 3461. The method of claim 3460, further comprisingsupporting the insulated conductor on a support member.
 3462. The methodof claim 3460, further comprising supporting the insulated conductor ona support member and maintaining a location of the first insulatedconductor on the support member with a centralizer.
 3463. The method ofclaim 3460, wherein the insulated conductor is coupled to two additionalinsulated conductors, wherein the insulated conductor and the twoinsulated conductors are disposed within the opening, and wherein thethree insulated conductors are electrically coupled in a 3-phase Yconfiguration.
 3464. The method of claim 3460, wherein an additionalinsulated conductor is disposed within the opening.
 3465. The method ofclaim 3460, wherein an additional insulated conductor is disposed withinthe opening, and wherein the insulated conductor and the additionalinsulated conductor are electrically coupled in a series configuration.3466. The method of claim 3460, wherein an additional insulatedconductor is disposed within the opening, and wherein the insulatedconductor and the additional insulated conductor are electricallycoupled in a parallel configuration.
 3467. The method of claim 3460,wherein the provided heat comprises approximately 500 W/m toapproximately 1150 W/m.
 3468. The method of claim 3460, wherein thecopper-nickel alloy is disposed in an electrically insulating material.3469. The method of claim 3460, wherein the copper-nickel alloy isdisposed in an electrically insulating material, and wherein theelectrically insulating material comprises magnesium oxide.
 3470. Themethod of claim 3460, wherein the copper-nickel alloy is disposed in anelectrically insulating material, wherein the electrically insulatingmaterial comprises magnesium oxide, and wherein the magnesium oxidecomprises a thickness of at least approximately 1 mm.
 3471. The methodof claim 3460, wherein the copper-nickel alloy is disposed in anelectrically insulating material, and wherein the electricallyinsulating material comprises aluminum oxide and magnesium oxide. 3472.The method of claim 3460, wherein the copper-nickel alloy is disposed inan electrically insulating material, wherein the electrically insulatingmaterial comprises magnesium oxide, wherein the magnesium oxidecomprises grain particles, and wherein the grain particles areconfigured to occupy porous spaces within the magnesium oxide.
 3473. Themethod of claim 3460, wherein the copper-nickel alloy is disposed in anelectrically insulating material, wherein the insulating material isdisposed in a sheath, and wherein the sheath comprises acorrosion-resistant material.
 3474. The method of claim 3460, whereinthe copper-nickel alloy is disposed in an electrically insulatingmaterial, wherein the insulating material is disposed in a sheath, andwherein the sheath comprises stainless steel.
 3475. The method of claim3460, further comprising supporting the insulated conductor on a supportmember and flowing a fluid into the opening through an orifice in thesupport member.
 3476. The method of claim 3460, further comprisingsupporting the insulated conductor on a support member and flowing asubstantially constant amount of fluid into the opening through criticalflow orifices in the support member.
 3477. The method of claim 3460,wherein a perforated tube is disposed in the opening proximate to theinsulated conductor, the method further comprising flowing a fluid intothe opening through the perforated tube.
 3478. The method of claim 3460,wherein a tube is disposed in the opening proximate to the insulatedconductor, the method further comprising flowing a substantiallyconstant amount a fluid into the opening through critical flow orificesin the tube.
 3479. The method of claim 3460, further comprisingsupporting the insulated conductor on a support member and flowing acorrosion inhibiting fluid into the opening through an orifice in thesupport member.
 3480. The method of claim 3460, wherein a perforatedtube is disposed in the opening proximate to the insulated conductor,the method further comprising flowing a corrosion inhibiting fluid intothe opening through the perforated tube.
 3481. The method of claim 3460,further comprising determining a temperature distribution in theinsulated conductor using an electromagnetic signal provided to theinsulated conductor.
 3482. The method of claim 3460, further comprisingmonitoring a leakage current of the insulated conductor.
 3483. Themethod of claim 3460, further comprising monitoring the appliedelectrical current.
 3484. The method of claim 3460, further comprisingmonitoring a voltage applied to the insulated conductor.
 3485. Themethod of claim 3460, further comprising monitoring a temperature in theinsulated conductor with at least one thermocouple.
 3486. The method ofclaim 3460, further comprising electrically coupling a lead-in conductorto the insulated conductor, wherein the lead-in conductor comprises alow resistance conductor configured to generate substantially no heat.3487. The method of claim 3460, further comprising electrically couplinga lead-in conductor to the insulated conductor using a cold pintransition conductor.
 3488. The method of claim 3460, further comprisingelectrically coupling a lead-in conductor to the insulated conductorusing a cold pin transition conductor, wherein the cold pin transitionconductor comprises a substantially low resistance insulated conductor.3489. The method of claim 3460, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation.
 3490. The method of claim3460, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in an overburden of theformation, and wherein the overburden casing comprises steel.
 3491. Themethod of claim 3460, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3492. The method of claim 3460, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3493. The method of claim 3460, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the method further comprises inhibiting a flow of fluid betweenthe opening and the overburden casing with a packing material.
 3494. Themethod of claim 3460, further comprising heating at least the portion ofthe formation to substantially pyrolyze at least some hydrocarbonswithin the formation.
 3495. A system configured to heat a coalformation, comprising: at least three insulated conductors disposedwithin an opening in the formation, wherein at least the three insulatedconductors are electrically coupled in a 3-phase Y configuration, andwherein at least the three insulated conductors are configured toprovide heat to at least a portion of the formation during use; andwherein the system is configured to allow heat to transfer from at leastthe three insulated conductors to a selected section of the formationduring use.
 3496. The system of claim 3495, wherein at least the threeinsulated conductors are further configured to generate heat duringapplication of an electrical current to at least the three insulatedconductors during use.
 3497. The system of claim 3495, furthercomprising a support member, wherein the support member is configured tosupport at least the three insulated conductors.
 3498. The system ofclaim 3495, further comprising a support member and a centralizer,wherein the support member is configured to support at least the threeinsulated conductors, and wherein the centralizer is configured tomaintain a location of at least the three insulated conductors on thesupport member.
 3499. The system of claim 3495, wherein the openingcomprises a diameter of at least approximately 5 cm.
 3500. The system ofclaim 3495, further comprising at least one lead-in conductor coupled toat least the three insulated conductors, wherein at least the onelead-in conductor comprises a low resistance conductor configured togenerate substantially no heat.
 3501. The system of claim 3495, furthercomprising at least one lead-in conductor coupled to at least the threeinsulated conductors, wherein at least the one lead-in conductorcomprises a rubber insulated conductor.
 3502. The system of claim 3495,further comprising at least one lead-in conductor coupled to at leastthe three insulated conductors, wherein at least the one lead-inconductor comprises a copper wire.
 3503. The system of claim 3495,further comprising at least one lead-in conductor coupled to at leastthe three insulated conductors with a cold pin transition conductor.3504. The system of claim 3495, further comprising at least one lead-inconductor coupled to at least the three insulated conductors with a coldpin transition conductor, wherein the cold pin transition conductorcomprises a substantially low resistance insulated conductor.
 3505. Thesystem of claim 3495, wherein at least the three insulated conductorscomprise a conductor disposed in an electrically insulating material,and wherein the electrically insulating material is disposed in asheath.
 3506. The system of claim 3495, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, and wherein the conductor comprises a copper-nickelalloy.
 3507. The system of claim 3495, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, wherein the conductor comprises a copper-nickelalloy, and wherein the copper-nickel alloy comprises approximately 7%nickel by weight to approximately 12% nickel by weight.
 3508. The systemof claim 3495, wherein at least the three insulated conductors comprisea conductor disposed in an electrically insulating material, wherein theconductor comprises a copper-nickel alloy, and wherein the copper-nickelalloy comprises approximately 2% nickel by weight to approximately 6%nickel by weight.
 3509. The system of claim 3495, wherein at least thethree insulated conductors comprise a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material comprises a thermally conductive material.
 3510. Thesystem of claim 3495, wherein at least the three insulated conductorscomprise a conductor disposed in an electrically insulating material,and wherein the electrically insulating material comprises magnesiumoxide.
 3511. The system of claim 3495, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, wherein the electrically insulating materialcomprises magnesium oxide, and wherein the magnesium oxide comprises athickness of at least approximately 1 mm.
 3512. The system of claim3495, wherein at least the three insulated conductors comprise aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material comprises aluminum oxide andmagnesium oxide.
 3513. The system of claim 3495, wherein the insulatedconductor comprises a conductor disposed in an electrically insulatingmaterial, wherein the electrically insulating material comprisesmagnesium oxide, wherein the magnesium oxide comprises grain particles,and wherein the grain particles are configured to occupy porous spaceswithin the magnesium oxide.
 3514. The system of claim 3495, wherein atleast the three insulated conductors comprise a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material is disposed in a sheath, and wherein the sheathcomprises a corrosion-resistant material.
 3515. The system of claim3495, wherein at least the three insulated conductors comprise aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material is disposed in a sheath, andwherein the sheath comprises stainless steel.
 3516. The system of claim3495, wherein at least the three insulated conductors are configured togenerate radiant heat of approximately 500 W/m to approximately 1150 W/mof at least the three insulated conductors during use.
 3517. The systemof claim 3495, further comprising a support member configured to supportat least the three insulated conductors, wherein the support membercomprises orifices configured to provide fluid flow through the supportmember into the opening during use.
 3518. The system of claim 3495,further comprising a support member configured to support at least thethree insulated conductors, wherein the support member comprisescritical flow orifices configured to provide a substantially constantamount of fluid flow through the support member into the opening duringuse.
 3519. The system of claim 3495, further comprising a tube coupledto at least the three insulated conductors, wherein the tube isconfigured to provide a flow of fluid into the opening during use. 3520.The system of claim 3495, further comprising a tube coupled to at leastthe three insulated conductors, wherein the tube comprises critical floworifices configured to provide a substantially constant amount of fluidflow through the support member into the opening during use.
 3521. Thesystem of claim 3495, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation.
 3522. The system of claim 3495, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3523. The system of claim 3495,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3524. Thesystem of claim 3495, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the opening.
 3525. The system ofclaim 3495, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configured to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 3526. The system of claim3495, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 3527. The system of claim 3495, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, the system furthercomprising a wellhead coupled to the overburden casing and a lead-inconductor coupled to the insulated conductor, wherein the wellhead isdisposed external to the overburden, wherein the wellhead comprises atleast one sealing flange, and wherein at least the one sealing flange isconfigured to couple to the lead-in conductor.
 3528. The system of claim3495, wherein the system is further configured to transfer heat suchthat the transferred heat can pyrolyze at least some hydrocarbons in theselected section.
 3529. A system configurable to heat a coal formation,comprising: at least three insulated conductors configurable to bedisposed within an opening in the formation, wherein at least the threeinsulated conductors are electrically coupled in a 3-phase Yconfiguration, and wherein at least the three insulated conductors arefurther configurable to provide heat to at least a portion of theformation during use; and wherein the system is configurable to allowheat to transfer from at least the three insulated conductors to aselected section of the formation during use.
 3530. The system of claim3529, wherein at least the three insulated conductors are furtherconfigurable to generate heat during application of an electricalcurrent to at least the three insulated conductors during use.
 3531. Thesystem of claim 3529, further comprising a support member, wherein thesupport member is configurable to support at least the three insulatedconductors.
 3532. The system of claim 3529, further comprising a supportmember and a centralizer, wherein the support member is configurable tosupport at least the three insulated conductors, and wherein thecentralizer is configurable to maintain a location of at least the threeinsulated conductors on the support member.
 3533. The system of claim3529, wherein the opening comprises a diameter of at least approximately5 cm.
 3534. The system of claim 3529, further comprising at least onelead-in conductor coupled to at least the three insulated conductors,wherein at least the one lead-in conductor comprises a low resistanceconductor configurable to generate substantially no heat.
 3535. Thesystem of claim 3529, further comprising at least one lead-in conductorcoupled to at least the three insulated conductors, wherein at least theone lead-in conductor comprises a rubber insulated conductor.
 3536. Thesystem of claim 3529, further comprising at least one lead-in conductorcoupled to at least the three insulated conductors, wherein at least theone lead-in conductor comprises a copper wire.
 3537. The system of claim3529, further comprising at least one lead-in conductor coupled to atleast the three insulated conductors with a cold pin transitionconductor.
 3538. The system of claim 3529, further comprising at leastone lead-in conductor coupled to at least the three insulated conductorswith a cold pin transition conductor, wherein the cold pin transitionconductor comprises a substantially low resistance insulated conductor.3539. The system of claim 3529, wherein at least the three insulatedconductors comprise a conductor disposed in an electrically insulatingmaterial, and wherein the electrically insulating material is disposedin a sheath.
 3540. The system of claim 3529, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, and wherein the conductor comprises a copper-nickelalloy.
 3541. The system of claim 3529, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, wherein the conductor comprises a copper-nickelalloy, and wherein the copper-nickel alloy comprises approximately 7%nickel by weight to approximately 12% nickel by weight.
 3542. The systemof claim 3529, wherein at least the three insulated conductors comprisea conductor disposed in an electrically insulating material, wherein theconductor comprises a copper-nickel alloy. and wherein the copper-nickelalloy comprises approximately 2% nickel by weight to approximately 6%nickel by weight.
 3543. The system of claim 3529, wherein at least thethree insulated conductors comprise a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material comprises a thermally conductive material.
 3544. Thesystem of claim 3529, wherein at least the three insulated conductorscomprise a conductor disposed in an electrically insulating material,and wherein the electrically insulating material comprises magnesiumoxide.
 3545. The system of claim 3529, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, wherein the electrically insulating materialcomprises magnesium oxide, and wherein the magnesium oxide comprises athickness of at least approximately 1 mm.
 3546. The system of claim3529, wherein at least the three insulated conductors comprise aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material comprises aluminum oxide andmagnesium oxide.
 3547. The system of claim 3529, wherein the insulatedconductor comprises a conductor disposed in an electrically insulatingmaterial, wherein the electrically insulating material comprisesmagnesium oxide, wherein the magnesium oxide comprises grain particles,and wherein the grain particles are configurable to occupy porous spaceswithin the magnesium oxide.
 3548. The system of claim 3529, wherein atleast the three insulated conductors comprise a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material is disposed in a sheath, and wherein the sheathcomprises a corrosion-resistant material.
 3549. The system of claim3529, wherein at least the three insulated conductors comprise aconductor disposed in an electrically insulating material, and whereinthe electrically insulating material is disposed in a sheath, andwherein the sheath comprises stainless steel.
 3550. The system of claim3529, wherein at least the three insulated conductors are configurableto generate radiant heat of approximately 500 W/m to approximately 1150W/m during use.
 3551. The system of claim 3529, further comprising asupport member configurable to support at least the three insulatedconductors, wherein the support member comprises orifices configurableto provide fluid flow through the support member into the opening duringuse.
 3552. The system of claim 3529, further comprising a support memberconfigurable to support at least the three insulated conductors, whereinthe support member comprises critical flow orifices configurable toprovide a substantially constant amount of fluid flow through thesupport member into the opening during use.
 3553. The system of claim3529, further comprising a tube coupled to at least the three insulatedconductors, wherein the tube is configurable to provide a flow of fluidinto the opening during use.
 3554. The system of claim 3529, furthercomprising a tube coupled to at least the three insulated conductors,wherein the tube comprises critical flow orifices configurable toprovide a substantially constant amount of fluid flow through thesupport member into the opening during use.
 3555. The system of claim3529, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation.
 3556. The system of claim 3529, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3557. The system of claim 3529,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3558. Thesystem of claim 3529, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the opening.
 3559. The system ofclaim 3529, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis configurable to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 3560. The system of claim3529, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation, wherein a packing material is disposed at a junction of theoverburden casing and the opening, and wherein the packing materialcomprises cement.
 3561. The system of claim 3529, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, the system furthercomprising a wellhead coupled to the overburden casing and a lead-inconductor coupled to the insulated conductor, wherein the wellhead isdisposed external to the overburden, wherein the wellhead comprises atleast one sealing flange, and wherein at least the one sealing flange isconfigurable to couple to the lead-in conductor.
 3562. The system ofclaim 3529, wherein the system is further configured to transfer heatsuch that the transferred heat can pyrolyze at least some hydrocarbonsin the selected section.
 3563. An in situ method for heating a coalformation, comprising: applying an electrical current to at least threeinsulated conductors to provide heat to at least a portion of theformation, wherein at least the three insulated conductors are disposedwithin an opening in the formation; and allowing the heat to transferfrom at least the three insulated conductors to a selected section ofthe formation.
 3564. The method of claim 3563, further comprisingsupporting at least the three insulated conductors on a support member.3565. The method of claim 3563, further comprising supporting at leastthe three insulated conductors on a support member and maintaining alocation of at least the three insulated conductors on the supportmember with a centralizer.
 3566. The method of claim 3563, wherein theprovided heat comprises approximately 500 W/m to approximately 1150 W/m.3567. The method of claim 3563, wherein at least the three insulatedconductors comprise a conductor disposed in an electrically insulatingmaterial, and wherein the conductor comprises a copper-nickel alloy.3568. The method of claim 3563, wherein at least the three insulatedconductors comprise a conductor disposed in an electrically insulatingmaterial, wherein the conductor comprises a copper-nickel alloy, andwherein the copper-nickel alloy comprises approximately 7% nickel byweight to approximately 12% nickel by weight.
 3569. The method of claim3563, wherein at least the three insulated conductors comprise aconductor disposed in an electrically insulating material, wherein theconductor comprises a copper-nickel alloy, and wherein the copper-nickelalloy comprises approximately 2% nickel by weight to approximately 6%nickel by weight.
 3570. The method of claim 3563, wherein at least thethree insulated conductors comprise a conductor disposed in anelectrically insulating material, and wherein the electricallyinsulating material comprises magnesium oxide.
 3571. The method of claim3563, wherein at least the three insulated conductors comprise aconductor disposed in an electrically insulating material, wherein theelectrically insulating material comprises magnesium oxide, and whereinthe magnesium oxide comprises a thickness of at least approximately 1mm.
 3572. The method of claim 3563, wherein at least the three insulatedconductors comprise a conductor disposed in an electrically insulatingmaterial, and wherein the electrically insulating material comprisesaluminum oxide and magnesium oxide.
 3573. The method of claim 3563,wherein at least the three insulated conductors comprise a conductordisposed in an electrically insulating material, wherein theelectrically insulating material comprises magnesium oxide, wherein themagnesium oxide comprises grain particles, and wherein the grainparticles are configured to occupy porous spaces within the magnesiumoxide.
 3574. The method of claim 3563, wherein at least the threeinsulated conductors comprise a conductor disposed in an electricallyinsulating material, wherein the insulating material is disposed in asheath, and wherein the sheath comprises a corrosion-resistant material.3575. The method of claim 3563, wherein at least the three insulatedconductors comprise a conductor disposed in an electrically insulatingmaterial, wherein the insulating material is disposed in a sheath, andwherein the sheath comprises stainless steel.
 3576. The method of claim3563, further comprising supporting at least the three insulatedconductors on a support member and flowing a fluid into the openingthrough an orifice in the support member.
 3577. The method of claim3563, further comprising supporting at least the three insulatedconductors on a support member and flowing a substantially constantamount of fluid into the opening through critical flow orifices in thesupport member.
 3578. The method of claim 3563, wherein a perforatedtube is disposed in the opening proximate to at least the threeinsulated conductors, the method further comprising flowing a fluid intothe opening through the perforated tube.
 3579. The method of claim 3563,wherein a tube is disposed in the opening proximate to at least thethree insulated conductors, the method further comprising flowing asubstantially constant amount a fluid into the opening through criticalflow orifices in the tube.
 3580. The method of claim 3563, furthercomprising supporting at least the three insulated conductors on asupport member and flowing a corrosion inhibiting fluid into the openingthrough an orifice in the support member.
 3581. The method of claim3563, wherein a perforated tube is disposed in the opening proximate toat least the three insulated conductors, the method further comprisingflowing a corrosion inhibiting fluid into the opening through theperforated tube.
 3582. The method of claim 3563, further comprisingdetermining a temperature distribution in at least the three insulatedconductors using an electromagnetic signal provided to the insulatedconductor.
 3583. The method of claim 3563, further comprising monitoringa leakage current of at least the three insulated conductors.
 3584. Themethod of claim 3563, further comprising monitoring the appliedelectrical current.
 3585. The method of claim 3563 further comprisingmonitoring a voltage applied to at least the three insulated conductors.3586. The method of claim 3563, further comprising monitoring atemperature in at least the three insulated conductors with at least onethermocouple.
 3587. The method of claim 3563, further comprisingelectrically coupling a lead-in conductor to at least the threeinsulated conductors, wherein the lead-in conductor comprises a lowresistance conductor configured to generate substantially no heat. 3588.The method of claim 3563, further comprising electrically coupling alead-in conductor to at least the three insulated conductors using acold pin transition conductor.
 3589. The method of claim 3563, furthercomprising electrically coupling a lead-in conductor to at least thethree insulated conductors using a cold pin transition conductor,wherein the cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 3590. The method of claim 3563, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3591.The method of claim 3563, further comprising coupling an overburdencasing to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3592. The method of claim 3563, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing is further disposed in cement.
 3593. The method of claim 3563,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3594. The method of claim 3563, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the method further comprises inhibiting a flow of fluid betweenthe opening and the overburden casing with a packing material.
 3595. Themethod of claim 3563, further comprising heating at least the portion ofthe formation to substantially pyrolyze at least some of thehydrocarbons within the formation.
 3596. A system configured to heat acoal formation, comprising: a first conductor disposed in a firstconduit, wherein the first conduit is disposed within an opening in theformation, and wherein the first conductor is configured to provide heatto at least a portion of the formation during use; and wherein thesystem is configured to allow heat to transfer from the first conductorto a section of the formation during use.
 3597. The system of claim3596, wherein the first conductor is further configured to generate heatduring application of an electrical current to the first conductor.3598. The system of claim 3596, wherein the first conductor comprises apipe.
 3599. The system of claim 3596, wherein the first conductorcomprises stainless steel.
 3600. The system of claim 3596, wherein thefirst conduit comprises stainless steel.
 3601. The system of claim 3596,further comprising a centralizer configured to maintain a location ofthe first conductor within the first conduit.
 3602. The system of claim3596, further comprising a centralizer configured to maintain a locationof the first conductor within the first conduit, wherein the centralizercomprises ceramic material.
 3603. The system of claim 3596, furthercomprising a centralizer configured to maintain a location of the firstconductor within the first conduit, wherein the centralizer comprisesceramic material and stainless steel.
 3604. The system of claim 3596,wherein the opening comprises a diameter of at least approximately 5 cm.3605. The system of claim 3596, further comprising a lead-in conductorcoupled to the first conductor, wherein the lead-in conductor comprisesa low resistance conductor configured to generate substantially no heat.3606. The system of claim 3596, further comprising a lead-in conductorcoupled to the first conductor, wherein the lead-in conductor comprisescopper.
 3607. The system of claim 3596, further comprising a slidingelectrical connector coupled to the first conductor.
 3608. The system ofclaim 3596, further comprising a sliding electrical connector coupled tothe first conductor, wherein the sliding electrical connector is furthercoupled to the first conduit.
 3609. The system of claim 3596, furthercomprising a sliding electrical connector coupled to the firstconductor, wherein the sliding electrical connector is further coupledto the first conduit, and wherein the sliding electrical connector isconfigured to complete an electrical circuit with the first conductorand the first conduit.
 3610. The system of claim 3596, furthercomprising a second conductor disposed within the first conduit and atleast one sliding electrical connector coupled to the first conductorand the second conductor, wherein at least the one sliding electricalconnector is configured to generate less heat than the first conductoror the second conductor during use.
 3611. The system of claim 3596,wherein the first conduit comprises a first section and a secondsection, wherein a thickness of the first section is greater than athickness of the second section such that heat radiated from the firstconductor to the section along the first section of the conduit is lessthan heat radiated from the first conductor to the section along thesecond section of the conduit.
 3612. The system of claim 3596, furthercomprising a fluid disposed within the first conduit, wherein the fluidis configured to maintain a pressure within the first conduit tosubstantially inhibit deformation of the first conduit during use. 3613.The system of claim 3596, further comprising a thermally conductivefluid disposed within the first conduit.
 3614. The system of claim 3596,further comprising a thermally conductive fluid disposed within thefirst conduit, wherein the thermally conductive fluid comprises helium.3615. The system of claim 3596, further comprising a fluid disposedwithin the first conduit, wherein the fluid is configured tosubstantially inhibit arcing between the first conductor and the firstconduit during use.
 3616. The system of claim 3596, further comprising atube disposed within the opening external to the first conduit, whereinthe tube is configured to remove vapor produced from at least the heatedportion of the formation such that a pressure balance is maintainedbetween the first conduit and the opening to substantially inhibitdeformation of the first conduit during use.
 3617. The system of claim3596, wherein the first conductor is further configured to generateradiant heat of approximately 650 W/m to approximately 1650 W/m duringuse.
 3618. The system of claim 3596, further comprising a secondconductor disposed within a second conduit and a third conductordisposed within a third conduit, wherein first conduit, the secondconduit and the third conduit are disposed in different openings of theformation, wherein the first conductor is electrically coupled to thesecond conductor and the third conductor, and wherein the first, second,and third conductors are configured to operate in a 3-phase Yconfiguration during use.
 3619. The system of claim 3596, furthercomprising a second conductor disposed within the first conduit, whereinthe second conductor is electrically coupled to the first conductor toform an electrical circuit.
 3620. The system of claim 3596, furthercomprising a second conductor disposed within the first conduit, whereinthe second conductor is electrically coupled to the first conductor toform an electrical circuit with a connector.
 3621. The system of claim3596, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation.
 3622. The system of claim 3596, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3623. The system of claim 3596,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3624. Thesystem of claim 3596, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the opening.
 3625. The system ofclaim 3596, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis further configured to substantially inhibit a flow of fluid betweenthe opening and the overburden casing during use.
 3626. The system ofclaim 3596, farther comprising an overburden casing coupled to theopening and a substantially low resistance conductor disposed within theoverburden casing, wherein the substantially low resistance conductor iselectrically coupled to the first conductor.
 3627. The system of claim3596, further comprising an overburden casing coupled to the opening anda substantially low resistance conductor disposed within the overburdencasing, wherein the substantially low resistance conductor iselectrically coupled to the first conductor, and wherein thesubstantially low resistance conductor comprises carbon steel.
 3628. Thesystem of claim 3596, further comprising an overburden casing coupled tothe opening and a substantially low resistance conductor disposed withinthe overburden casing and a centralizer configured to support thesubstantially low resistance conductor within the overburden casing.3629. The system of claim 3596, wherein the heated section of theformation is substantially pyrolyzed.
 3630. A system configurable toheat a coal formation, comprising: a first conductor configurable to bedisposed in a first conduit, wherein the first conduit is configurableto be disposed within an opening in the formation, and wherein the firstconductor is further configurable to provide heat to at least a portionof the formation during use; and wherein the system is configurable toallow heat to transfer from the first conductor to a section of theformation during use.
 3631. The system of claim 3630, wherein the firstconductor is further configurable to generate heat during application ofan electrical current to the first conductor.
 3632. The system of claim3630, wherein the first conductor comprises a pipe.
 3633. The system ofclaim 3630, wherein the first conductor comprises stainless steel. 3634.The system of claim 3630, wherein the first conduit comprises stainlesssteel.
 3635. The system of claim 3630, further comprising a centralizerconfigurable to maintain a location of the first conductor within thefirst conduit.
 3636. The system of claim 3630, further comprising acentralizer configurable to maintain a location of the first conductorwithin the first conduit, wherein the centralizer comprises ceramicmaterial.
 3637. The system of claim 3630, further comprising acentralizer configurable to maintain a location of the first conductorwithin the first conduit, wherein the centralizer comprises ceramicmaterial and stainless steel.
 3638. The system of claim 3630, whereinthe opening comprises a diameter of at least approximately 5 cm. 3639.The system of claim 3630, further comprising a lead-in conductor coupledto the first conductor, wherein the lead-in conductor comprises a lowresistance conductor configurable to generate substantially no heat.3640. The system of claim 3630, further comprising a lead-in conductorcoupled to the first conductor wherein the lead-in conductor comprisescopper.
 3641. The system of claim 3630, further comprising a slidingelectrical connector coupled to the first conductor.
 3642. The system ofclaim 3630, further comprising a sliding electrical connector coupled tothe first conductor, wherein the sliding electrical connector is furthercoupled to the first conduit.
 3643. The system of claim 3630, furthercomprising a sliding electrical connector coupled to the firstconductor, wherein the sliding electrical connector is further coupledto the first conduit, and wherein the sliding electrical connector isconfigurable to complete an electrical circuit with the first conductorand the first conduit.
 3644. The system of claim 3630, furthercomprising a second conductor disposed within the first conduit and atleast one sliding electrical connector coupled to the first conductorand the second conductor, wherein at least the one sliding electricalconnector is configurable to generate less heat than the first conductoror the second conductor during use.
 3645. The system of claim 3630,wherein the first conduit comprises a first section and a secondsection, wherein a thickness of the first section is greater than athickness of the second section such that heat radiated from the firstconductor to the section along the first section of the conduit is lessthan heat radiated from the first conductor to the section along thesecond section of the conduit.
 3646. The system of claim 3630, furthercomprising a fluid disposed within the first conduit, wherein the fluidis configurable to maintain a pressure within the first conduit tosubstantially inhibit deformation of the first conduit during use. 3647.The system of claim 3630, further comprising a thermally conductivefluid disposed within the first conduit.
 3648. The system of claim 3630,further comprising a thermally conductive fluid disposed within thefirst conduit, wherein the thermally conductive fluid comprises helium.3649. The system of claim 3630, further comprising a fluid disposedwithin the first conduit, wherein the fluid is configurable tosubstantially inhibit arcing between the first conductor and the firstconduit during use.
 3650. The system of claim 3630, further comprising atube disposed within the opening external to the first conduit, whereinthe tube is configurable to remove vapor produced from at least theheated portion of the formation such that a pressure balance ismaintained between the first conduit and the opening to substantiallyinhibit deformation of the first conduit during use.
 3651. The system ofclaim 3630, wherein the first conductor is further configurable togenerate radiant heat of approximately 650 W/m to approximately 1650 W/mduring use.
 3652. The system of claim 3630, further comprising a secondconductor disposed within a second conduit and a third conductordisposed within a third conduit, wherein first conduit, the secondconduit and the third conduit are disposed in different openings of theformation, wherein the first conductor is electrically coupled to thesecond conductor and the third conductor, and wherein the first, second,and third conductors are configurable to operate in a 3-phase Yconfiguration during use.
 3653. The system of claim 3630, furthercomprising a second conductor disposed within the first conduit, whereinthe second conductor is electrically coupled to the first conductor toform an electrical circuit.
 3654. The system of claim 3630, furthercomprising a second conductor disposed within the first conduit, whereinthe second conductor is electrically coupled to the first conductor toform an electrical circuit with a connector.
 3655. The system of claim3630, further comprising an overburden casing coupled to the opening,wherein the overburden casing is disposed in an overburden of theformation.
 3656. The system of claim 3630, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3657. The system of claim 3630,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3658. Thesystem of claim 3630, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the opening.
 3659. The system ofclaim 3630, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis further configurable to substantially inhibit a flow of fluid betweenthe opening and the overburden casing during use.
 3660. The system ofclaim 3630, further comprising an overburden casing coupled to theopening and a substantially low resistance conductor disposed within theoverburden, casing, wherein the substantially low resistance conductoris electrically coupled to the first conductor.
 3661. The system ofclaim 3630, further comprising an overburden casing coupled to theopening and a substantially low resistance conductor disposed within theoverburden casing, wherein the substantially low resistance conductor iselectrically coupled to the first conductor, and wherein thesubstantially low resistance conductor comprises carbon steel.
 3662. Thesystem of claim 3630, further comprising an overburden casing coupled tothe opening and a substantially low resistance conductor disposed withinthe overburden casing and a centralizer configurable to support thesubstantially low resistance conductor within the overburden casing.3663. The system of claim 3630, wherein the heated section of theformation is substantially pyrolyzed.
 3664. An in situ method forheating a coal formation, comprising: applying an electrical current toa first conductor to provide heat to at least a portion of theformation, wherein the first conductor is disposed in a first conduit,and wherein the first conduit is disposed within an opening in theformation; and allowing the heat to transfer from the first conductor toa section of the formation.
 3665. The method of claim 3664, wherein thefirst conductor comprises a pipe.
 3666. The method of claim 3664,wherein the first conductor comprises stainless steel.
 3667. The methodof claim 3664, wherein the first conduit comprises stainless steel.3668. The method of claim 3664, further comprising maintaining alocation of the first conductor in the first conduit with a centralizer.3669. The method of claim 3664, further comprising maintaining alocation of the first conductor in the first conduit with a centralizer,wherein the centralizer comprises ceramic material.
 3670. The method ofclaim 3664, further comprising maintaining a location of the firstconductor in the first conduit with a centralizer, wherein thecentralizer comprises ceramic material and stainless steel.
 3671. Themethod of claim 3664, further comprising coupling a sliding electricalconnector to the first conductor.
 3672. The method of claim 3664,further comprising electrically coupling a sliding electrical connectorto the first conductor and the first conduit, wherein the first conduitcomprises an electrical lead configured to complete an electricalcircuit with the first conductor.
 3673. The method of claim 3664,further comprising coupling a sliding electrical connector to the firstconductor and the first conduit, wherein the first conduit comprises anelectrical lead configured to complete an electrical circuit with thefirst conductor, and wherein the generated heat comprises approximately20 percent generated by the first conduit.
 3674. The method of claim3664, wherein the provided heat comprises approximately 650 W/m toapproximately 1650 W/m.
 3675. The method of claim 3664, furthercomprising determining a temperature distribution in the first conduitusing an electromagnetic signal provided to the conduit.
 3676. Themethod of claim 3664, further comprising monitoring the appliedelectrical current.
 3677. The method of claim 3664, further comprisingmonitoring a voltage applied to the first conductor.
 3678. The method ofclaim 3664, further comprising monitoring a temperature in the conduitwith at least one thermocouple.
 3679. The method of claim 3664, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3680.The method of claim 3664, further comprising coupling an overburdencasing to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3681. The method of claim 3664, further comprising coupling anoverburden casing,to the opening, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing is further disposed in cement.
 3682. The method of claim 3664,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in an overburden of the formation andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3683. The method of claim 3664, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the method further comprises inhibiting a flow of fluid betweenthe opening and the overburden casing with a packing material.
 3684. Themethod of claim 3664, further comprising coupling an overburden casingto the opening, wherein a substantially low resistance conductor isdisposed within the overburden casing, and wherein the substantially lowresistance conductor is electrically coupled to the first conductor.3685. The method of claim 3664, further comprising coupling anoverburden casing to the opening, wherein a substantially low resistanceconductor is disposed within the overburden casing, wherein thesubstantially low resistance conductor is electrically coupled to thefirst conductor, and wherein the substantially low resistance conductorcomprises carbon steel.
 3686. The method of claim 3664, furthercomprising coupling an overburden casing to the opening, wherein asubstantially low resistance conductor is disposed within the overburdencasing, wherein the substantially low resistance conductor iselectrically coupled to the first conductor, and wherein the methodfurther comprises maintaining a location of the substantially lowresistance conductor in the overburden casing with a centralizersupport.
 3687. The method of claim 3664, further comprising electricallycoupling a lead-in conductor to the first conductor, wherein the lead-inconductor comprises a low resistance conductor configured to generatesubstantially no heat.
 3688. The method of claim 3664, furthercomprising electrically coupling a lead-in conductor to the firstconductor, wherein the lead-in conductor comprises copper.
 3689. Themethod of claim 3664, further comprising maintaining a sufficientpressure between the first conduit and the formation to substantiallyinhibit deformation of the first conduit.
 3690. The method of claim3664, further comprising providing a thermally conductive fluid withinthe first conduit.
 3691. The method of claim 3664, further comprisingproviding a thermally conductive fluid within the first conduit, whereinthe thermally conductive fluid comprises helium.
 3692. The method ofclaim 3664, further comprising inhibiting arcing between the firstconductor and the first conduit with a fluid disposed within the firstconduit.
 3693. The method of claim 3664, further comprising removing avapor from the opening using a perforated tube disposed proximate to thefirst conduit in the opening to control a pressure in the opening. 3694.The method of claim 3664, further comprising flowing a corrosioninhibiting fluid through a perforated tube disposed proximate to thefirst conduit in the opening.
 3695. The method of claim 3664, wherein asecond conductor is disposed within the first conduit, wherein thesecond conductor is electrically coupled to the first conductor to forman electrical circuit.
 3696. The method of claim 3664, wherein a secondconductor is disposed within the first conduit, wherein the secondconductor is electrically coupled to the first conductor with aconnector.
 3697. The method of claim 3664, wherein a second conductor isdisposed within a second conduit and a third conductor is disposedwithin a third conduit, wherein the second conduit and the third conduitare disposed in different openings of the formation, wherein the firstconductor is electrically coupled to the second conductor and the thirdconductor, and wherein the first, second, and third conductors areconfigured to operate in a 3-phase Y configuration.
 3698. The method ofclaim 3664, wherein a second conductor is disposed within the firstconduit, wherein at least one sliding electrical connector is coupled tothe first conductor and the second conductor, and wherein heat generatedby at least the one sliding electrical connector is less than heatgenerated by the first conductor or the second conductor.
 3699. Themethod of claim 3664, wherein the first conduit comprises a firstsection and a second section, wherein a thickness of the first sectionis greater than a thickness of the second section such that heatradiated from the first conductor to the section along the first sectionof the conduit is less than heat radiated from the first conductor tothe section along the second section of the conduit.
 3700. The method ofclaim 3664, further comprising flowing an oxidizing fluid through anorifice in the first conduit.
 3701. The method of claim 3664, furthercomprising disposing a perforated tube proximate to the first conduitand flowing an oxidizing fluid through the perforated tube.
 3702. Themethod of claim 3664, further comprising heating at least the portion ofthe formation to substantially pyrolyze at least some of the carbonwithin the formation.
 3703. A system configured to heat a coalformation, comprising: a first conductor disposed in a first conduit,wherein the first conduit is disposed within a first opening in theformation; a second conductor disposed in a second conduit, wherein thesecond conduit is disposed within a second opening in the formation; athird conductor disposed in a third conduit, wherein the third conduitis disposed within a third opening in the formation, wherein the first,second, and third conductors are electrically coupled in a 3-phase Yconfiguration, and wherein the first, second, and third conductors areconfigured to provide heat to at least a portion of the formation duringuse; and wherein the system is configured to allow heat to transfer fromthe first, second, and third conductors to a selected section of theformation during use.
 3704. The system of claim 3703, wherein the first,second, and third conductors are further configured to generate heatduring application of an electrical current to the first conductor.3705. The system of claim 3703, wherein the first, second, and thirdconductors comprise a pipe.
 3706. The system of claim 3703, wherein thefirst, second, and third conductors comprise stainless steel.
 3707. Thesystem of claim 3703, wherein the first, second, and third openingscomprise a diameter of at least approximately 5 cm.
 3708. The system ofclaim 3703, further comprising a first sliding electrical connectorcoupled to the first conductor and a second sliding electrical connectorcoupled to the second conductor and a third sliding electrical connectorcoupled to the third conductor.
 3709. The system of claim 3703, furthercomprising a first sliding electrical connector coupled to the firstconductor, wherein the first sliding electrical connector is furthercoupled to the first conduit.
 3710. The system of claim 3703, furthercomprising a second sliding electrical connector coupled to the secondconductor, wherein the second sliding electrical connector is furthercoupled to the second conduit.
 3711. The system of claim 3703, farthercomprising a third sliding electrical connector coupled to the thirdconductor, wherein the third sliding electrical connector is furthercoupled to the third conduit.
 3712. The system of claim 3703, whereineach of the first, second, and third conduits comprises a first sectionand a second section, wherein a thickness of the first section isgreater than a thickness of the second section such that heat radiatedfrom each of the first, second, and third conductors to the sectionalong the first section of each of the conduits is less than heatradiated from the first, second, and third conductors to the sectionalong the second section of each of the conduits.
 3713. The system ofclaim 3703, further comprising a fluid disposed within the first,second, and third conduits, wherein the fluid is configured to maintaina pressure within the first conduit to substantially inhibit deformationof the first, second, and third conduits during use.
 3714. The system ofclaim 3703, further comprising a thermally conductive fluid disposedwithin the first, second, and third conduits.
 3715. The system of claim3703, further comprising a thermally conductive fluid disposed withinthe first, second, and third conduits, wherein the thermally conductivefluid comprises helium.
 3716. The system of claim 3703, furthercomprising a fluid disposed within the first, second, and thirdconduits, wherein the fluid is configured to substantially inhibitarcing between the first, second, and third conductors and the first,second, and third conduits during use.
 3717. The system of claim 3703,further comprising at least one tube disposed within the first, second,and third openings external to the first, second, and third conduits,wherein at least the one tube is configured to remove vapor producedfrom at least the heated portion of the formation such that a pressurebalance is maintained between the first, second, and third conduits andthe first, second, and third openings to substantially inhibitdeformation of the first, second, and third conduits during use. 3718.The system of claim 3703, wherein the first, second, and thirdconductors are further configured to generate radiant heat ofapproximately 650 W/m to approximately 1650 W/m during use.
 3719. Thesystem of claim 3703, further comprising at least one overburden casingcoupled to the first, second, and third openings, wherein at least theone overburden casing is disposed in an overburden of the formation.3720. The system of claim 3703, further comprising at least oneoverburden casing coupled to the first, second, and third openings,wherein at least the one overburden casing is disposed in an overburdenof the formation, and wherein at least the one overburden casingcomprises steel.
 3721. The system of claim 3703, further comprising atleast one overburden casing coupled to the first, second, and thirdopenings, wherein at least the one overburden casing is disposed in anoverburden of the formation, and wherein at least the one overburdencasing is further disposed in cement.
 3722. The system of claim 3703,further comprising at least one overburden casing coupled to the first,second, and third openings, wherein at least the one overburden casingis disposed in an overburden of the formation, and wherein a packingmaterial is disposed at a junction of at least the one overburden casingand the first, second, and third openings.
 3723. The system of claim3703, further comprising at least one overburden casing coupled to thefirst, second, and third openings, wherein at least the one overburdencasing is disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of at least the one overburden casingand the first, second, and third openings, and wherein the packingmaterial is further configured to substantially inhibit a flow of fluidbetween the first, second, and third opening and at least the oneoverburden casing during use.
 3724. The system of claim 3703, whereinthe heated section of the formation is substantially pyrolyzed.
 3725. Asystem configurable to heat a coal formation, comprising: a firstconductor configurable to be disposed in a first conduit, wherein thefirst conduit is configurable to be disposed within a first opening inthe formation; a second conductor configurable to be disposed in asecond conduit, wherein the second conduit is configurable to bedisposed within a second opening in the formation; a third conductorconfigurable to be disposed in a third conduit, wherein the thirdconduit is configurable to be disposed within a third opening in theformation, wherein the first, second, and third conductors are furtherconfigurable to be electrically coupled in a 3-phase Y configuration,and wherein the first, second, and third conductors are furtherconfigurable to provide heat to at least a portion of the formationduring use; and wherein the system is configurable to allow heat totransfer from the first, second, and third conductors to a selectedsection of the formation during use.
 3726. The system of claim 3725,wherein the first, second, and third conductors are further configurableto generate heat during application of an electrical current to thefirst conductor.
 3727. The system of claim 3725, wherein the first,second, and third conductors comprise a pipe.
 3728. The system of claim3725, wherein the first, second, and third conductors comprise stainlesssteel.
 3729. The system of claim 3725, wherein the first, second, andthird opening comprise a diameter of at least approximately 5 cm. 3730.The system of claim 3725, further comprising a first sliding electricalconnector coupled to the first conductor and a second sliding electricalconnector coupled to the second conductor and a third sliding electricalconnector coupled to the third conductor.
 3731. The system of claim3725, further comprising a first sliding electrical connector coupled tothe first conductor, wherein the first sliding electrical connector isfurther coupled to the first conduit.
 3732. The system of claim 3725,further comprising a second sliding electrical connector coupled to thesecond conductor, wherein the second sliding electrical connector isfurther coupled to the second conduit.
 3733. The system of claim 3725,further comprising a third sliding electrical connector coupled to thethird conductor, wherein the third sliding electrical connector isfurther coupled to the third conduit.
 3734. The system of claim 3725,wherein each of the first, second, and third conduits comprises a firstsection and a second section, wherein a thickness of the first sectionis greater than a thickness of the second section such that heatradiated from each of the first, second, and third conductors to thesection along the first section of each of the conduits is less thanheat radiated from the first, second, and third conductors to thesection along the second section of each of the conduits.
 3735. Thesystem of claim 3725, further comprising a fluid disposed within thefirst, second, and third conduits, wherein the fluid is configurable tomaintain a pressure within the first conduit to substantially inhibitdeformation of the first, second, and third conduits during use. 3736.The system of claim 3725, further comprising a thermally conductivefluid disposed within the first, second, and third conduits.
 3737. Thesystem of claim 3725, further comprising a thermally conductive fluiddisposed within the first, second, and third conduits, wherein thethermally conductive fluid comprises helium.
 3738. The system of claim3725, further comprising a fluid disposed within the first, second, andthird conduits, wherein the fluid is configurable to substantiallyinhibit arcing between the first, second, and third conductors and thefirst, second, and third conduits during use.
 3739. The system of claim3725, further comprising at least one tube disposed within the first,second, and third openings external to the first, second, and thirdconduits, wherein at least the one tube is configurable to remove vaporproduced from at least the heated portion of the formation such that apressure balance is maintained between the first, second, and thirdconduits and the first, second, and third openings to substantiallyinhibit deformation of the first, second, and third conduits during use.3740. The system of claim 3725, wherein the first, second, and thirdconductors are further configurable to generate radiant heat ofapproximately 650 W/m to approximately 1650 W/m during use.
 3741. Thesystem of claim 3725, further comprising at least one overburden casingcoupled to the first, second, and third openings, wherein at least theone overburden casing is disposed in an overburden of the formation.3742. The system of claim 3725, further comprising at least oneoverburden casing coupled to the first, second, and third openings,wherein at least the one overburden casing is disposed in an overburdenof the formation, and wherein at least the one overburden casingcomprises steel.
 3743. The system of claim 3725, further comprising atleast one overburden casing coupled to the first, second, and thirdopenings, wherein at least the one overburden casing is disposed in anoverburden of the formation, and wherein at least the one overburdencasing is further disposed in cement.
 3744. The system of claim 3725,further comprising at least one overburden casing coupled to the first,second, and third openings, wherein at least the one overburden casingis disposed in an overburden of the formation, and wherein a packingmaterial is disposed at a junction of at least the one overburden casingand the first, second, and third openings.
 3745. The system of claim3725, further comprising at least one overburden casing coupled to thefirst, second, and third openings, wherein at least the one overburdencasing is disposed in an overburden of the formation, wherein a packingmaterial is disposed at a junction of at least the one overburden casingand the first, second, and third openings, and wherein the packingmaterial is further configurable to substantially inhibit a flow offluid between the first, second, and third opening and at least the oneoverburden casing during use.
 3746. The system of claim 3725, whereinthe heated section of the formation is substantially pyrolyzed.
 3747. Anin situ method for heating a coal formation, comprising: applying anelectrical current to a first conductor to provide heat to at least aportion of the formation, wherein the first conductor is disposed in afirst conduit, and wherein the first conduit is disposed within a firstopening in the formation; applying an electrical current to a secondconductor to provide heat to at least a portion of the formation,wherein the second conductor is disposed in a second conduit, andwherein the second conduit is disposed within a second opening in theformation; applying an electrical current to a third conductor toprovide heat to at least a portion of the formation, wherein the thirdconductor is disposed in a third conduit, and wherein the third conduitis disposed within a third opening in the formation; and allowing theheat to transfer from the first, second, and third conductors to aselected section of the formation.
 3748. The method of claim 3747,wherein the first, second, and third conductors comprise a pipe. 3749.The method of claim 3747, wherein the first, second, and thirdconductors comprise stainless steel.
 3750. The method of claim 3747,wherein the first, second, and third conduits comprise stainless steel.3751. The method of claim 3747, wherein the provided heat comprisesapproximately 650 W/m to approximately 1650 W/m.
 3752. The method ofclaim 3747, further comprising determining a temperature distribution inthe first, second, and third conduits using an electromagnetic signalprovided to the first, second, and third conduits.
 3753. The method ofclaim 3747, further comprising monitoring the applied electricalcurrent.
 3754. The method of claim 3747, further comprising monitoring avoltage applied to the first, second, and third conductors.
 3755. Themethod of claim 3747, further comprising monitoring a temperature in thefirst, second, and third conduits with at least one thermocouple. 3756.The method of claim 3747, further comprising maintaining a sufficientpressure between the first, second, and third conduits and the first,second, and third openings to substantially inhibit deformation of thefirst, second, and third conduits.
 3757. The method of claim 3747,further comprising providing a thermally conductive fluid within thefirst, second, and third conduits.
 3758. The method of claim 3747,further comprising providing a thermally conductive fluid within thefirst, second, and third conduits, wherein the thermally conductivefluid comprises helium.
 3759. The method of claim 3747, furthercomprising inhibiting arcing between the first, second, and thirdconductors and the first, second, and third conduits with a fluiddisposed within the first, second, and third conduits.
 3760. The methodof claim 3747, further comprising removing a vapor from the first,second, and third openings using at least one perforated tube disposedproximate to the first, second, and third conduits in the first, second,and third openings to control a pressure in the first, second, and thirdopenings.
 3761. The method of claim 3747, wherein the first, second, andthird conduits comprise a first section and a second section, wherein athickness of the first section is greater than a thickness of the secondsection such that heat radiated from the first, second, and thirdconductors to the section along the first section of the first, second,and third conduits is less than heat radiated from the first, second,and third conductors to the section along the second section of thefirst, second, and third conduits.
 3762. The method of claim 3747,further comprising flowing an oxidizing fluid through an orifice in thefirst, second, and third conduits.
 3763. The method of claim 3747,further comprising heating at least the portion of the formation tosubstantially pyrolyze at least some of the carbon within the formation.3764. A system configured to heat a coal formation, comprising: a firstconductor disposed in a conduit, wherein the conduit is disposed withinan opening in the formation; and a second conductor disposed in theconduit, wherein the second conductor is electrically coupled to thefirst conductor with a connector, and wherein the first and secondconductors are configured to provide heat to at least a portion of theformation during use; and wherein the system is configured to allow heatto transfer from the first and second conductors to a selected sectionof the formation during use.
 3765. The system of claim 3764, wherein thefirst conductor is further configured to generate heat duringapplication of an electrical current to the first conductor.
 3766. Thesystem of claim 3764, wherein the first and second conductors comprise apipe.
 3767. The system of claim 3764, wherein the first and secondconductors comprise stainless steel.
 3768. The system of claim 3764,wherein the conduit comprises stainless steel.
 3769. The system of claim3764, further comprising a centralizer configured to maintain a locationof the first and second conductors within the conduit.
 3770. The systemof claim 3764, further comprising a centralizer configured to maintain alocation of the first and second conductors within the conduit, whereinthe centralizer comprises ceramic material.
 3771. The system of claim3764, further comprising a centralizer configured to maintain a locationof the first and second conductors within the conduit, wherein thecentralizer comprises ceramic material and stainless steel.
 3772. Thesystem of claim 3764, wherein the opening comprises a diameter of atleast approximately 5 cm.
 3773. The system of claim 3764, furthercomprising a lead-in conductor coupled to the first and secondconductors, wherein the lead-in conductor comprises a low resistanceconductor configured to generate substantially no heat.
 3774. The systemof claim 3764, further comprising a lead-in conductor coupled to thefirst and second conductors, wherein the lead-in conductor comprisescopper.
 3775. The system of claim 3764, wherein the conduit comprises afirst section and a second section, wherein a thickness of the firstsection is greater than a thickness of the second section such that heatradiated from the first conductor to the section along the first sectionof the conduit is less than heat radiated from the first conductor tothe section along the second section of the conduit.
 3776. The system ofclaim 3764, further comprising a fluid disposed within the conduit,wherein the fluid is configured to maintain a pressure within theconduit to substantially inhibit deformation of the conduit during use.3777. The system of claim 3764, further comprising a thermallyconductive fluid disposed within the conduit.
 3778. The system of claim3764, further comprising a thermally conductive fluid disposed withinthe conduit, wherein the thermally conductive fluid comprises helium.3779. The system of claim 3764, further comprising a fluid disposedwithin the conduit, wherein the fluid is configured to substantiallyinhibit arcing between the first and second conductors and the conduitduring use.
 3780. The system of claim 3764, further comprising a tubedisposed within the opening external to the conduit, wherein the tube isconfigured to remove vapor produced from at least the heated portion ofthe formation such that a pressure balance is maintained between theconduit and the opening to substantially inhibit deformation of theconduit during use.
 3781. The system-of claim 3764, wherein the firstand second conductors are further configured to generate radiant heat ofapproximately 650 W/m to approximately 1650 W/m during use.
 3782. Thesystem of claim 3764, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation.
 3783. The system of claim 3764, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3784. The system of claim 3764,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3785. Thesystem of claim 3764, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the opening.
 3786. The system ofclaim 3764, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis further configured to substantially inhibit a flow of fluid betweenthe opening and the overburden casing during use.
 3787. The system ofclaim 3764, wherein the heated section of the formation is substantiallypyrolyzed.
 3788. A system configurable to heat a coal formation,comprising: a first conductor configurable to be disposed in a conduit,wherein the conduit is configurable to be disposed within an opening inthe formation; and a second conductor configurable to be disposed in theconduit, wherein the second conductor is configurable to be electricallycoupled to the first conductor with a connector, and wherein the firstand second conductors are further configurable to provide heat to atleast a portion of the formation during use; and wherein the system isconfigurable to allow heat to transfer from the first and secondconductors to a selected section of the formation during use.
 3789. Thesystem of claim 3788, wherein the first conductor is furtherconfigurable to generate heat during application of an electricalcurrent to the first conductor.
 3790. The system of claim 3788, whereinthe first and second conductors comprise a pipe.
 3791. The system ofclaim 3788, wherein the first and second conductors comprise stainlesssteel.
 3792. The system of claim 3788, wherein the conduit comprisesstainless steel.
 3793. The system of claim 3788, further comprising acentralizer configurable to maintain a location of the first and secondconductors within the conduit.
 3794. The system of claim 3788, furthercomprising a centralizer configurable to maintain a location of thefirst and second conductors within the conduit, wherein the centralizercomprises ceramic material.
 3795. The system of claim 3788, furthercomprising a centralizer configurable to maintain a location of thefirst and second conductors within the conduit, wherein the centralizercomprises ceramic material and stainless steel.
 3796. The system ofclaim 3788, wherein the opening comprises a diameter of at leastapproximately 5 cm.
 3797. The system of claim 3788, further comprising alead-in conductor coupled to the first and second conductors, whereinthe lead-in conductor comprises a low resistance conductor configurableto generate substantially no heat.
 3798. The system of claim 3788,further comprising a lead-in conductor coupled to the first and secondconductors, wherein the lead-in conductor comprises copper.
 3799. Thesystem of claim 3788, wherein the conduit comprises a first section anda second section, wherein a thickness of the first section is greaterthan a thickness of the second section such that heat radiated from thefirst conductor to the section along the first section of the conduit isless than heat radiated from the first conductor to the section alongthe second section of the conduit.
 3800. The system of claim 3788,further comprising a fluid disposed within the conduit, wherein thefluid is configurable to maintain a pressure within the conduit tosubstantially inhibit deformation of the conduit during use.
 3801. Thesystem of claim 3788, further comprising a thermally conductive fluiddisposed within the conduit.
 3802. The system of claim 3788, furthercomprising a thermally conductive fluid disposed within the conduit,wherein the thermally conductive fluid comprises helium.
 3803. Thesystem of claim 3788, further comprising a fluid disposed within theconduit, wherein the fluid is configurable to substantially inhibitarcing between the first and second conductors and the conduit duringuse.
 3804. The system of claim 3788, further comprising a tube disposedwithin the opening external to the conduit, wherein the tube isconfigurable to remove vapor produced from at least the heated portionof the formation such that a pressure balance is maintained between theconduit and the opening to substantially inhibit deformation of theconduit during use.
 3805. The system of claim 3788, wherein the firstand second conductors are further configurable to generate radiant heatof approximately 650 W/m to approximately 1650 W/m during use.
 3806. Thesystem of claim 3788, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation.
 3807. The system of claim 3788, further comprising anoverburden casing coupled to the opening, wherein the overburden casingis disposed in an overburden of the formation, and wherein theoverburden casing comprises steel.
 3808. The system of claim 3788,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 3809. Thesystem of claim 3788, further comprising an overburden casing coupled tothe opening, wherein the overburden casing is disposed in an overburdenof the formation, and wherein a packing material is disposed at ajunction of the overburden casing and the opening.
 3810. The system ofclaim 3788, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, wherein a packing material is disposed at a junction ofthe overburden casing and the opening, and wherein the packing materialis further configurable to substantially inhibit a flow of fluid betweenthe opening and the overburden casing during use.
 3811. The system ofclaim 3788, wherein the heated section of the formation is substantiallypyrolyzed.
 3812. An in situ method for heating a coal formation,comprising: applying an electrical current to at least two conductors toprovide heat to at least a portion of the formation, wherein at leastthe two conductors are disposed within a conduit, wherein the conduit isdisposed within an opening in the formation, and wherein at least thetwo conductors are electrically coupled with a connector; and allowingheat to transfer from at least the two conductors to a selected sectionof the formation.
 3813. The method of claim 3812, wherein at least thetwo conductors comprise a pipe.
 3814. The method of claim 3812, whereinat least the two conductors comprise stainless steel.
 3815. The methodof claim 3812, wherein the conduit comprises stainless steel.
 3816. Themethod of claim 3812, further comprising maintaining a location of atleast the two conductors in the conduit with a centralizer.
 3817. Themethod of claim 3812, further comprising maintaining a location of atleast the two conductors in the conduit with a centralizer, wherein thecentralizer comprises ceramic material.
 3818. The method of claim 3812,further comprising maintaining a location of at least the two conductorsin the conduit with a centralizer, wherein the centralizer comprisesceramic material and stainless steel.
 3819. The method of claim 3812,wherein the provided heat comprises approximately 650 W/m toapproximately 1650 W/m.
 3820. The method of claim 3812, furthercomprising determining a temperature distribution in the conduit usingan electromagnetic signal provided to the conduit.
 3821. The method ofclaim 3812, further comprising monitoring the applied electricalcurrent.
 3822. The method of claim 3812, further comprising monitoring avoltage applied to at least the two conductors.
 3823. The method ofclaim 3812, further comprising monitoring a temperature in the conduitwith at least one thermocouple.
 3824. The method of claim 3812, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3825.The method of claim 3812, further comprising coupling an overburdencasing to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3826. The method of claim 3812, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing is further disposed in cement.
 3827. The method of claim 3812,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3828. The method of claim 3812, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the method further comprises inhibiting a flow of fluid bet weenthe opening and the overburden casing with a packing material.
 3829. Themethod of claim 3812, further comprising maintaining a sufficientpressure between the conduit and the formation to substantially inhibitdeformation of the conduit.
 3830. The method of claim 3812, furthercomprising providing a thermally conductive fluid within the conduit.3831. The method of claim 3812, further comprising providing a thermallyconductive fluid within the conduit, wherein the thermally conductivefluid comprises helium.
 3832. The method of claim 3812, furthercomprising inhibiting arcing between at least the two conductors and theconduit with a fluid disposed within the conduit.
 3833. The method ofclaim 3812, further comprising removing a vapor from the opening using aperforated tube disposed proximate to the conduit in the opening tocontrol a pressure in the opening.
 3834. The method of claim 3812,further comprising flowing a corrosion inhibiting fluid through aperforated tube disposed proximate to the conduit in the opening. 3835.The method of claim 3812, wherein the conduit comprises a first sectionand a second section, wherein a thickness of the first section isgreater than a thickness of the second section such that heat radiatedfrom the first conductor to the section along the first section of theconduit is less than heat radiated from the first conductor to thesection along the second section of the conduit.
 3836. The method ofclaim 3812, further comprising flowing an oxidizing fluid through anorifice in the conduit.
 3837. The method of claim 3812, furthercomprising disposing a perforated tube proximate to the conduit andflowing an oxidizing fluid through the perforated tube.
 3838. The methodof claim 3812, further comprising heating at least the portion of theformation to substantially pyrolyze at least some of the carbon withinthe formation.
 3839. A system configured to heat a coal formation,comprising: at least one conductor disposed in a conduit, wherein theconduit is disposed within an opening in the formation, and wherein atleast the one conductor is configured to provide heat to at least afirst portion of the formation during use; at least one slidingconnector, wherein at least the one sliding connector is coupled to atleast the one conductor, wherein at least the one sliding connector isconfigured to provide heat during use, and wherein heat provided by atleast the one sliding connector is substantially less than the heatprovided by at least the one conductor during use; and wherein thesystem is configured to allow heat to transfer from at least the oneconductor to a section of the formation during use.
 3840. The system ofclaim 3839, wherein at least the one conductor is further configured togenerate heat during application of an electrical current to at leastthe one conductor.
 3841. The system of claim 3839, wherein at least theone conductor comprises a pipe.
 3842. The system of claim 3839, whereinat least the one conductor comprises stainless steel.
 3843. The systemof claim 3839, wherein the conduit comprises stainless steel. a locationof at least the one conductor within the conduit.
 3844. The system ofclaim 3839, further comprising a centralizer configured to maintain alocation of at least the one conductor within the conduit.
 3845. Thesystem of claim 3839, further comprising a centralizer configured tomaintain a location of at least the one conductor within the conduit,wherein the centralizer comprises ceramic material.
 3846. The system ofclaim 3839, further comprising a centralizer configured to maintain alocation of at least the one conductor within the conduit, wherein thecentralizer comprises ceramic material and stainless steel.
 3847. Thesystem of claim 3839, wherein the opening comprises a diameter of atleast approximately 5 cm.
 3848. The system of claim 3839, furthercomprising a lead-in conductor coupled to at least the one conductor,wherein the lead-in conductor comprises a low resistance conductorconfigured to generate substantially no heat.
 3849. The system of claim3839, further comprising a lead-in conductor coupled to at least the oneconductor, wherein the lead-in conductor comprises copper.
 3850. Thesystem of claim 3839, wherein the conduit comprises a first section anda second section, wherein a thickness of the first section is greaterthan a thickness of the second section such that heat radiated from thefirst conductor to the section along the first section of the conduit isless than heat radiated from the first conductor to the section alongthe second section of the conduit.
 3851. The system of claim 3839,further comprising a fluid disposed within the conduit, wherein thefluid is configured to maintain a pressure within the conduit tosubstantially inhibit deformation of the conduit during use.
 3852. Thesystem of claim 3839, further comprising a thermally conductive fluiddisposed within the conduit.
 3853. The system of claim 3839, furthercomprising a thermally conductive fluid disposed within the conduit,wherein the thermally conductive fluid comprises helium.
 3854. Thesystem of claim 3839, further comprising a fluid disposed within theconduit, wherein the fluid is configured to substantially inhibit arcingbetween at least the one conductor and the conduit during use.
 3855. Thesystem of claim 3839, further comprising a tube disposed within theopening external to the conduit, wherein the tube is configured toremove vapor produced from at least the heated portion of the formationsuch that a pressure balance is maintained between the conduit and theopening to substantially inhibit deformation of the conduit during use.3856. The system of claim 3839, wherein at least the one conductor isfurther configured to generate radiant heat of approximately 650 W/m toapproximately 1650 W/m during use.
 3857. The system of claim 3839,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation.3858. The system of claim 3839, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3859. The system of claim 3839, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3860. The system of claim 3839, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3861. The system of claim 3839, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material is further configuredto substantially inhibit a flow of fluid between the opening and theoverburden casing during use.
 3862. The system of claim 3839, furthercomprising an overburden casing coupled to the opening and asubstantially low resistance conductor disposed within the overburdencasing, wherein the substantially low resistance conductor iselectrically coupled to at least the one conductor.
 3863. The system ofclaim 3839, further comprising an overburden casing coupled to theopening and a substantially low resistance conductor disposed within theoverburden casing, wherein the substantially low resistance conductor iselectrically coupled to at least the one conductor, and wherein thesubstantially low resistance conductor comprises carbon steel.
 3864. Thesystem of claim 3839, further comprising an overburden casing coupled tothe opening and a substantially low resistance conductor disposed withinthe overburden casing and a centralizer configured to support thesubstantially low resistance conductor within the overburden casing.3865. The system of claim 3839, wherein the heated section of theformation is substantially pyrolyzed.
 3866. A system configurable toheat a coal formation, comprising: at least one conductor configurableto be disposed in a conduit, wherein the conduit is configurable to bedisposed within an opening in the formation, and wherein at least theone conductor is further configurable to provide heat to at least afirst portion of the formation during use; at least one slidingconnector, wherein at least the one sliding connector is configurable tobe coupled to at least the one conductor, wherein at least the onesliding connector is further configurable to provide heat during use,and wherein heat provided by at least the one sliding connector issubstantially less than the heat provided by at least the one conductorduring use; and wherein the system is configurable to allow heat totransfer from at least the one conductor to a section of the formationduring use.
 3867. The system of claim 3866, wherein at least the oneconductor is further configurable to generate heat during application ofan electrical current to at least the one conductor.
 3868. The system ofclaim 3866, wherein at least the one conductor comprises a pipe. 3869.The system of claim 3866, wherein at least the one conductor comprisesstainless steel.
 3870. The system of claim 3866, wherein the conduitcomprises stainless steel.
 3871. The system of claim 3866, furthercomprising a centralizer configurable to maintain a location of at leastthe one conductor within the conduit.
 3872. The system of claim 3866,further comprising a centralizer configurable to maintain a location ofat least the one conductor within the conduit, wherein the centralizercomprises ceramic material.
 3873. The system of claim 3866, furthercomprising a centralizer configurable to maintain a location of at leastthe one conductor within the conduit, wherein the centralizer comprisesceramic material and stainless steel.
 3874. The system of claim 3866,wherein the opening comprises a diameter of at least approximately 5 cm.3875. The system of claim 3866, further comprising a lead-in conductorcoupled to at least the one conductor, wherein the lead-in conductorcomprises a low resistance conductor configurable to generatesubstantially no heat.
 3876. The system of claim 3866, furthercomprising a lead-in conductor coupled to at least the one conductor,wherein the lead-in conductor comprises copper.
 3877. The system ofclaim 3866, wherein the conduit comprises a first section and a secondsection, wherein a thickness of the first section is greater than athickness of the second section such that heat radiated from the firstconductor to the section along the first section of the conduit is lessthan heat radiated from the first conductor to the section along thesecond section of the conduit.
 3878. The system of claim 3866, furthercomprising a fluid disposed within the conduit, wherein the fluid isconfigurable to maintain a pressure within the conduit to substantiallyinhibit deformation of the conduit during use.
 3879. The system of claim3866, further comprising a thermally conductive fluid disposed withinthe conduit.
 3880. The system of claim 3866, further comprising athermally conductive fluid disposed within the conduit, wherein thethermally conductive fluid comprises helium.
 3881. The system of claim3866, further comprising a fluid disposed within the conduit, whereinthe fluid is configurable to substantially inhibit arcing between atleast the one conductor and the conduit during use.
 3882. The system ofclaim 3866, further comprising a tube disposed within the openingexternal to the conduit, wherein the tube is configurable to removevapor produced from at least the heated portion of the formation suchthat a pressure balance is maintained between the conduit and theopening to substantially inhibit deformation of the conduit during use.3883. The system of claim 3866, wherein at least the one conductor isfurther configurable to generate radiant heat of approximately 650 W/mto approximately 1650 W/m during use.
 3884. The system of claim 3866,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation.3885. The system of claim 3866, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3886. The system of claim 3866, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3887. The system of claim 3866, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3888. The system of claim 3866, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material is furtherconfigurable to substantially inhibit a flow of fluid between theopening and the overburden casing during use.
 3889. The system of claim3866, further comprising an overburden casing coupled to the opening anda substantially low resistance conductor disposed within the overburdencasing, wherein the substantially low resistance conductor iselectrically coupled to at least the one conductor.
 3890. The system ofclaim 3866, further comprising an overburden casing coupled to theopening and a substantially low resistance conductor disposed within theoverburden casing, wherein the substantially low resistance conductor iselectrically coupled to at least the one conductor, and wherein thesubstantially low resistance conductor comprises carbon steel.
 3891. Thesystem of claim 3866, further comprising an overburden casing coupled tothe opening and a substantially low resistance conductor disposed withinthe overburden casing and a centralizer configurable to support thesubstantially low resistance conductor within the overburden casing.3892. The system of claim 3866, wherein the heated section of theformation is substantially pyrolyzed.
 3893. An in situ method forheating a coal formation, comprising: applying an electrical current toat least one conductor and at least one sliding connector to provideheat to at least a portion of the formation, wherein at least the oneconductor and at least the one sliding connector are disposed within aconduit, and wherein heat provided by at least the one conductor issubstantially greater than heat provided by at least the one slidingconnector; and allowing the heat to transfer from at least the oneconductor and at least the one sliding connector to a section of theformation.
 3894. The method of claim 3893, wherein at least the oneconductor comprises a pipe.
 3895. The method of claim 3893, wherein atleast the one conductor comprises stainless steel.
 3896. The method ofclaim 3893, wherein the conduit comprises stainless steel.
 3897. Themethod of claim 3893, further comprising maintaining a location of atleast the one conductor in the conduit with a centralizer.
 3898. Themethod of claim 3893, further comprising maintaining a location of atleast the one conductor in the conduit with a centralizer, wherein thecentralizer comprises ceramic material.
 3899. The method of claim 3893,further comprising maintaining a location of at least the one conductorin the conduit with a centralizer, wherein the centralizer comprisesceramic material and stainless steel.
 3900. The method of claim 3893,wherein the provided heat comprises approximately 650 W/m toapproximately 1650 W/m.
 3901. The method of claim 3893, furthercomprising determining a temperature distribution in the conduit usingan electromagnetic signal provided to the conduit.
 3902. The method ofclaim 3893, further comprising monitoring the applied electricalcurrent.
 3903. The method of claim 3893, further comprising monitoring avoltage applied to at least the one conductor.
 3904. The method of claim3893, further comprising monitoring a temperature in the conduit with atleast one thermocouple.
 3905. The method of claim 3893, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3906.The method of claim 3893, further comprising coupling an overburdencasing to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3907. The method of claim 3893, further comprising coupling anoverburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing is further disposed in cement.
 3908. The method of claim 3893,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3909. The method of claim 3893, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the method further comprises inhibiting a flow of fluid bet weenthe opening and the overburden casing with a packing material.
 3910. Themethod of claim 3893, further comprising coupling an overburden casingto the opening, wherein a substantially low resistance conductor isdisposed within the overburden casing, and wherein the substantially lowresistance conductor is electrically coupled to at least the oneconductor.
 3911. The method of claim 3893, further comprising couplingan overburden casing to the opening, wherein a substantially lowresistance conductor is disposed within the overburden casing, whereinthe substantially low resistance conductor is electrically coupled to atleast the one conductor, and wherein the substantially low resistanceconductor comprises carbon steel.
 3912. The method of claim 3893,further comprising coupling an overburden casing to the opening, whereina substantially low resistance conductor is disposed within theoverburden casing, wherein the substantially low resistance conductor iselectrically coupled to at least the one conductor, and wherein themethod further comprises maintaining a location of the substantially lowresistance conductor in the overburden casing with a centralizersupport.
 3913. The method of claim 3893, further comprising electricallycoupling a lead-in conductor to at least the one conductor, wherein thelead-in conductor comprises a low resistance conductor configured togenerate substantially no heat.
 3914. The method of claim 3893, furthercomprising electrically coupling a lead-in conductor to at least the oneconductor, wherein the lead-in conductor comprises copper. t
 3915. Themethod of claim 3893, further comprising maintaining a sufficientpressure between the conduit and the formation to substantially inhibitdeformation of the conduit.
 3916. The method of claim 3893, furthercomprising providing a thermally conductive fluid within the conduit.3917. The method of claim 3893, further comprising providing a thermallyconductive fluid within the conduit, wherein the thermally conductivefluid comprises helium.
 3918. The method of claim 3893, furthercomprising inhibiting arcing between the conductor and the conduit witha fluid disposed within the conduit.
 3919. The method of claim 3893,further comprising removing a vapor from the opening using a perforatedtube disposed proximate to the conduit in the opening to control apressure in the opening.
 3920. The method of claim 3893, furthercomprising flowing a corrosion inhibiting fluid through a perforatedtube disposed proximate to the conduit in the opening.
 3921. The methodof claim 3893, further comprising flowing an oxidizing fluid through anorifice in the conduit.
 3922. The method of claim 3893, furthercomprising disposing a perforated tube proximate to the conduit andflowing an oxidizing fluid through the perforated tube.
 3923. The methodof claim 3893, further comprising heating at least the portion of theformation to substantially pyrolyze at least some of the carbon withinthe formation.
 3924. A system configured to heat a coal formation,comprising: at least one elongated member disposed within an opening inthe formation, wherein at least the one elongated member is configuredto provide heat to at least a portion of the formation during use; andwherein the system is configured to allow heat to transfer from at leastthe one elongated member to a section of the formation during use. 3925.The system of claim 3924, wherein at least the one elongated membercomprises stainless steel.
 3926. The system of claim 3924, wherein atleast the one elongated member is further configured to generate heatduring application of an electrical current to at least the oneelongated member.
 3927. The system of claim 3924, further comprising asupport member coupled to at least the one elongated member, wherein thesupport member is configured to support at least the one elongatedmember.
 3928. The system of claim 3924, further comprising a supportmember coupled to at least the one elongated member, wherein the supportmember is configured to support at least the one elongated member, andwherein the support member comprises openings.
 3929. The system of claim3924, further comprising a support member coupled to at least the oneelongated member, wherein the support member is configured to support atleast the one elongated member, wherein the support member comprisesopenings, wherein the openings are configured to flow a fluid along alength of at least the one elongated member during use, and wherein thefluid is configured to substantially inhibit carbon deposition on orproximate to at least the one elongated member during use.
 3930. Thesystem of claim 3924, further comprising a tube disposed in the opening,wherein the tube comprises openings, wherein the openings are configuredto flow a fluid along a length of at least the one elongated memberduring use, and wherein the fluid is configured to substantially inhibitcarbon deposition on or proximate to at least the one elongated memberduring use.
 3931. The system of claim 3924, further comprising acentralizer coupled to at least the one elongated member, wherein thecentralizer is configured to electrically isolate at least the oneelongated member.
 3932. The system of claim 3924, further comprising acentralizer coupled to at least the one elongated member and a supportmember coupled to at least the one elongated member, wherein thecentralizer is configured to maintain a location of at least the oneelongated member on the support member.
 3933. The system of claim 3924,wherein the opening comprises a diameter of at least approximately 5 cm.3934. The system of claim 3924, further comprising a lead-in conductorcoupled to at least the one elongated member, wherein the lead-inconductor comprises a low resistance conductor configured to generatesubstantially no heat.
 3935. The system of claim 3924, furthercomprising a lead-in conductor coupled to at least the one elongatedmember, wherein the lead-in conductor comprises a rubber insulatedconductor.
 3936. The system of claim 3924, further comprising a lead-inconductor coupled to at least the one elongated member, wherein thelead-in conductor comprises copper wire.
 3937. The system of claim 3924,further comprising a lead-in conductor coupled to at least the oneelongated member with a cold pin transition conductor.
 3938. The systemof claim 3924, further comprising a lead-in conductor coupled to atleast the one elongated member with a cold pin transition conductor,wherein the cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 3939. The system of claim 3924, whereinat least the one elongated member is arranged in a series electricalconfiguration.
 3940. The system of claim 3924, where in at least the oneelongated member is arranged in a parallel electrical configuration.3941. The system of claim 3924, wherein at least the one elongatedmember is configured to generate radiant heat of approximately 650 W/mto approximately 1650 W/m during use.
 3942. The system of claim 3924,further comprising a perforated tube disposed in the opening external toat least the one elongated member, wherein the perforated tube isconfigured to remove vapor from the opening to control a pressure in theopening during use.
 3943. The system of claim 3924, further comprisingan overburden casing coupled to the opening, wherein the overburdencasing is disposed in an overburden of the formation.
 3944. The systemof claim 3924, further comprising an overburden casing coupled to theopening, wherein the overburden casing is disposed in an overburden ofthe formation, and wherein the overburden casing comprises steel. 3945.The system of claim 3924, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3946. The system of claim 3924, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3947. The system of claim 3924, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3948. The system of claim 3924, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, wherein a packing material is disposed at ajunction of the overburden casing and the opening, and wherein thepacking material is further configured to substantially inhibit a flowof fluid between the opening and the overburden casing during use. 3949.The system of claim 3924, wherein the heated section of the formation issubstantially pyrolyzed.
 3950. A system configurable to heat a coalformation, comprising: at least one elongated member configurable to bedisposed within an opening in the formation, wherein at least the oneelongated member is further configurable to provide heat to at least aportion of the formation during use; and wherein the system isconfigurable to allow heat to transfer from at least the one elongatedmember to a section of the formation during use.
 3951. The system ofclaim 3950, wherein at least the one elongated member comprisesstainless steel.
 3952. The system of claim 3950, wherein at least theone elongated member is further configurable to generate heat duringapplication of an electrical current to at least the one elongatedmember.
 3953. The system of claim 3950, further comprising a supportmember coupled to at least the one elongated member, wherein the supportmember is configurable to support at least the one elongated member.3954. The system of claim 3950, further comprising a support membercoupled to at least the one elongated member, wherein the support memberis configurable to support at least the one elongated member, andwherein the support member comprises openings.
 3955. The system of claim3950, further comprising a support member coupled to at least the oneelongated member, wherein the support member is configurable to supportat least the one elongated member, wherein the support member comprisesopenings, wherein the openings are configurable to flow a fluid along alength of at least the one elongated member during use, and wherein thefluid is configurable to substantially inhibit carbon deposition on orproximate to at least the one elongated member during use.
 3956. Thesystem of claim 3950, further comprising a tube disposed in the opening,wherein the tube comprises openings, wherein the openings areconfigurable to flow a fluid along a length of at least the oneelongated member during use, and wherein the fluid is configurable tosubstantially inhibit carbon deposition on or proximate to at least theone elongated member during use.
 3957. The system of claim 3950, furthercomprising a centralizer coupled to at least the one elongated member,wherein the centralizer is configurable to electrically isolate at leastthe one elongated member.
 3958. The system of claim 3950, furthercomprising a centralizer coupled to at least the one elongated memberand a support member coupled to at least the one elongated member,wherein the centralizer is configurable to maintain a location of atleast the one elongated member on the support member.
 3959. The systemof claim 3950, wherein the opening comprises a diameter of at leastapproximately 5 cm.
 3960. The system of claim 3950, further comprising alead-in conductor coupled to at least the one elongated member, whereinthe lead-in conductor comprises a low resistance conductor configurableto generate substantially no heat.
 3961. The system of claim 3950,further comprising a lead-in conductor coupled to at least the oneelongated member, wherein the lead-in conductor comprises a rubberinsulated conductor.
 3962. The system of claim 3950, further comprisinga lead-in conductor coupled to at least the one elongated member,wherein the lead-in conductor comprises copper wire.
 3963. The system ofclaim 3950, further comprising a lead-in conductor coupled to at leastthe one elongated member with a cold pin transition conductor.
 3964. Thesystem of claim 3950, further comprising a lead-in conductor coupled toat least the one elongated member with a cold pin transition conductor,wherein the cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 3965. The system of claim 3950, whereinat least the one elongated member is arranged in a series electricalconfiguration.
 3966. The system of claim 3950, wherein at least the oneelongated member is arranged in a parallel electrical configuration.3967. The system of claim 3950, wherein at least the one elongatedmember is configurable to generate radiant heat of approximately 650 W/mto approximately 1650 W/m during use.
 3968. The system of claim 3950,further comprising a perforated tube disposed in the opening external toat least the one elongated member, wherein the perforated tube isconfigurable to remove vapor from the opening to control a pressure inthe opening during use.
 3969. The system of claim 3950, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 3970.The system of claim 3950, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 3971. The system of claim 3950, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 3972. The system of claim 3950, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 3973. The system of claim 3950, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.3974. The system of claim 3950, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, wherein a packing material is disposed at ajunction of the overburden casing and the opening, and wherein thepacking material is further configurable to substantially inhibit a flowof fluid between the opening and the overburden casing during use. 3975.The system of claim 3950, where in the heated section of the formationis substantially pyrolyzed.
 3976. An in situ method for heating a coalformation, comprising: applying an electrical current to at least oneelongated member to provide heat to at least a portion of the formation,wherein at least the one elongated member is disposed within an openingof the formation; and allowing heat to transfer from at least the oneelongated member to a section of the formation.
 3977. The method ofclaim 3976, wherein at least the one elongated member comprises a metalstrip.
 3978. The method of claim 3976, wherein at least the oneelongated member comprises a metal rod.
 3979. The method of claim 3976,wherein at least the one elongated member comprises stainless steel.3980. The method of claim 3976, further comprising supporting at leastthe one elongated member on a center support member.
 3981. The method ofclaim 3976, further comprising supporting at least the one elongatedmember on a center support member, wherein the center support membercomprises a tube.
 3982. The method of claim 3976, further comprisingelectrically isolating at least the one elongated member with acentralizer.
 3983. The method of claim 3976, further comprisinglaterally spacing at least the one elongated member with a centralizer.3984. The method of claim 3976, further comprising electrically couplingat least the one elongated member in a series configuration.
 3985. Themethod of claim 3976, further comprising electrically coupling at leastthe one elongated member in a parallel configuration.
 3986. The methodof claim 3976, wherein the provided heat comprises approximately 650 W/mto approximately 1650 W/m.
 3987. The method of claim 3976, furthercomprising determining a temperature distribution in at least the oneelongated member using an electromagnetic signal provided to at leastthe one elongated member.
 3988. The method of claim 3976, furthercomprising monitoring the applied electrical current.
 3989. The methodof claim 3976, further comprising monitoring a voltage applied to atleast the one elongated member.
 3990. The method of claim 3976, furthercomprising monitoring a temperature in at least the one elongated memberwith at least one thermocouple.
 3991. The method of claim 3976, furthercomprising supporting at least the one elongated member on a centersupport member, wherein the center support member comprises openings,the method further comprising flowing an oxidizing fluid through theopenings to substantially inhibit carbon deposition proximate to or onat least the one elongated member.
 3992. The method of claim 3976,further comprising flowing an oxidizing fluid through a tube disposedproximate to at least the one elongated member to substantially inhibitcarbon deposition proximate to or on at least the one elongated member.3993. The method of claim 3976, further comprising flowing an oxidizingfluid through an opening in at least the one elongated member tosubstantially inhibit carbon deposition proximate to or on at least theone elongated member.
 3994. The method of claim 3976, further comprisingelectrically coupling a lead-in conductor to at least the one elongatedmember, wherein the lead-in conductor comprises a low resistanceconductor configured to generate substantially no heat.
 3995. The methodof claim 3976, further comprising electrically coupling a lead-inconductor to at least the one elongated member using a cold pintransition conductor.
 3996. The method of claim 3976, further comprisingelectrically coupling a lead-in conductor to at least the one elongatedmember using a cold pin transition conductor, wherein the cold pintransition conductor comprises a substantially low resistance insulatedconductor.
 3997. The method of claim 3976, further comprising couplingan overburden casing to the opening, wherein the overburden casing isdisposed in an overburden of the formation.
 3998. The method of claim3976, further comprising coupling an overburden casing to the opening,wherein the overburden casing comprises steel.
 3999. The method of claim3976, further comprising coupling an overburden casing to the opening,wherein the overburden casing is disposed in cement.
 4000. The method ofclaim 3976, further comprising coupling an overburden casing to theopening, wherein a packing material is disposed at a junction of theoverburden casing and the opening.
 4001. The method of claim 3976,further comprising coupling an overburden casing to the opening, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the method further comprises inhibiting aflow of fluid between the opening and the overburden casing with thepacking material.
 4002. The method of claim 3976, further comprisingheating at least the portion of the formation to substantially pyrolyzeat least some of the carbon within the formation.
 4003. A systemconfigured to heat a coal formation, comprising: at least one elongatedmember disposed within an opening in the formation, wherein at least theone elongated member is configured to provide heat to at least a portionof the formation during use; an oxidizing fluid source; a conduitdisposed within the opening, wherein the conduit is configured toprovide an oxidizing fluid from the oxidizing fluid source to theopening during use, and wherein the oxidizing fluid is selected tosubstantially inhibit carbon deposition on or proximate to at least theone elongated member during use; and wherein the system is configured toallow heat to transfer from at least the one elongated member to asection of the formation during use.
 4004. The system of claim 4003,wherein at least the one elongated member comprises stainless steel.4005. The system of claim 4003, wherein at least the one elongatedmember is further configured to generate heat during application of anelectrical current to at least the one elongated member.
 4006. Thesystem of claim 4003, wherein at least the one elongated member iscoupled to the conduit, wherein the conduit is further configured tosupport at least the one elongated member.
 4007. The system of claim4003, wherein at least the one elongated member is coupled to theconduit, wherein the conduit is further configured to support at leastthe one elongated member, and wherein the conduit comprises openings.4008. The system of claim 4003, further comprising a centralizer coupledto at least the one elongated member and the conduit, wherein thecentralizer is configured to electrically isolate at least the oneelongated member from the conduit.
 4009. The system of claim 4003,further comprising a centralizer coupled to at least the one elongatedmember and the conduit, wherein the centralizer is configured tomaintain a location of at least the one elongated member on the conduit.4010. The system of claim 4003, wherein the opening comprises a diameterof at least approximately 5 cm.
 4011. The system of claim 4003, furthercomprising a lead-in conductor coupled to at least the one elongatedmember, wherein the lead-in conductor comprises a low resistanceconductor configured to generate substantially no heat.
 4012. The systemof claim 4003, further comprising a lead-in conductor coupled to atleast the one elongated member, wherein the lead-in conductor comprisesa rubber insulated conductor.
 4013. The system of claim 4003, furthercomprising a lead-in conductor coupled to at least the one elongatedmember, wherein the lead-in conductor comprises copper wire.
 4014. Thesystem of claim 4003, further comprising a lead-in conductor coupled toat least the one elongated member with a cold pin transition conductor.4015. The system of claim 4003, further comprising a lead-in conductorcoupled to at least the one elongated member with a cold pin transitionconductor, wherein the cold pin transition conductor comprises asubstantially low resistance insulated conductor.
 4016. The system ofclaim 4003, wherein at least the one elongated member is arranged in aseries electrical configuration.
 4017. The system of claim 4003, whereinat least the one elongated member is arranged in a parallel electricalconfiguration.
 4018. The system of claim 4003, wherein at least the oneelongated member is configured to generate radiant heat of approximately650 W/m to approximately 1650 W/m during use.
 4019. The system of claim4003, further comprising a perforated tube disposed in the openingexternal to at least the one elongated member, wherein the perforatedtube is configured to remove vapor from the opening to control apressure in the opening during use.
 4020. The system of claim 4003,further comprising an overburden casing coupled to the opening, whereinthe overburden casing is disposed in an overburden of the formation.4021. The system of claim 4003, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 4022. The system of claim 4003, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 4023. The system of claim 4003, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 4024. The system of claim 4003, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.4025. The system of claim 4003, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, wherein a packing material is disposed at ajunction of the overburden casing and the opening, and wherein thepacking material is further configured to substantially inhibit a flowof fluid between the opening and the overburden casing during use. 4026.The system of claim 4003, wherein the heated section of the formation issubstantially pyrolyzed.
 4027. A system configurable to heat a coalformation, comprising: at least one elongated member configurable to bedisposed within an opening in the formation, wherein at least the oneelongated member is further configurable to provide heat to at least aportion of the formation during use; a conduit configurable to bedisposed within the opening, wherein the conduit is further configurableto provide an oxidizing fluid from the oxidizing fluid source to theopening during use, and wherein the system is configurable to allow theoxidizing fluid to substantially inhibit carbon deposition on orproximate to at least the one elongated member during use; and whereinthe system is further configurable to allow heat to transfer from atleast the one elongated member to a section of the formation during use.4028. The system of claim 4027, wherein at least the one elongatedmember comprises stainless steel.
 4029. The system of claim 4027,wherein at least the one elongated member is further configurable togenerate heat during application of an electrical current to at leastthe one elongated member.
 4030. The system of claim 4027, wherein atleast the one elongated member is coupled to the conduit, wherein theconduit is further configurable to support at least the one elongatedmember.
 4031. The system of claim 4027, wherein at least the oneelongated member is coupled to the conduit, wherein the conduit isfurther configurable to support at least the one elongated member, andwherein the conduit comprises openings.
 4032. The system of claim 4027,further comprising a centralizer coupled to at least the one elongatedmember and the conduit, wherein the centralizer is configurable toelectrically isolate at least the one elongated member from the conduit.4033. The system of claim 4027, further comprising a centralizer coupledto at least the one elongated member and the conduit, wherein thecentralizer is configurable to maintain a location of at least the oneelongated member on the conduit.
 4034. The system of claim 4027, whereinthe opening comprises a diameter of at least approximately 5 cm. 4035.The system of claim 4027, further comprising a lead-in conductor coupledto at least the one elongated member, wherein the lead-in conductorcomprises a low resistance conductor configurable to generatesubstantially no heat.
 4036. The system of claim 4027, furthercomprising a lead-in conductor coupled to at least the one elongatedmember, wherein the lead-in conductor comprises a rubber insulatedconductor.
 4037. The system of claim 4027, further comprising a lead-inconductor coupled to at least the one elongated member, wherein thelead-in conductor comprises copper wire.
 4038. The system of claim 4027,further comprising a lead-in conductor coupled to at least the oneelongated member with a cold pin transition conductor.
 4039. The systemof claim 4027, further comprising a lead-in conductor coupled to atleast the one elongated member with a cold pin transition conductor,wherein the cold pin transition conductor comprises a substantially lowresistance insulated conductor.
 4040. The system of claim 4027, whereinat least the one elongated member is arranged in a series electricalconfiguration.
 4041. The system of claim 4027, wherein at least the oneelongated member is arranged in a parallel electrical configuration.4042. The system of claim 4027, wherein at least the one elongatedmember is configurable to generate radiant heat of approximately 650 W/mto approximately 1650 W/m during use.
 4043. The system of claim 4027,further comprising a perforated tube disposed in the opening external toat least the one elongated member, wherein the perforated tube isconfigurable to remove vapor from the opening to control a pressure inthe opening during use.
 4044. The system of claim 4027, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation. 4045.The system of claim 4027, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing comprisessteel.
 4046. The system of claim 4027, further comprising an overburdencasing coupled to the opening, wherein the overburden casing is disposedin an overburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 4047. The system of claim 4027, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, andwherein a packing material is disposed at a junction of the overburdencasing and the opening.
 4048. The system of claim 4027, furthercomprising an overburden casing coupled to the opening, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the opening, and wherein the packing material comprises cement.4049. The system of claim 4027, further comprising an overburden casingcoupled to the opening, wherein the overburden casing is disposed in anoverburden of the formation, wherein a packing material is disposed at ajunction of the overburden casing and the opening, and wherein thepacking material is further configurable to substantially inhibit a flowof fluid between the opening and the overburden casing during use. 4050.The system of claim 4027, where in the heated section of the formationis substantially pyrolyzed.
 4051. An in situ method for heating a coalformation, comprising: applying an electrical current to at least oneelongated member to provide heat to at least a portion of the formation,wherein at least the one elongated member is disposed within an openingin the formation; providing an oxidizing fluid to at least the oneelongated member to substantially inhibit carbon deposition on orproximate to at least the one elongated member; and allowing heat totransfer from at least the one elongated member to a section of theformation.
 4052. The method of claim 4051, wherein at least the oneelongated member comprises a metal strip.
 4053. The method of claim4051, wherein at least the one elongated member comprises a metal rod.4054. The method of claim 4051, wherein at least the one elongatedmember comprises stainless steel.
 4055. The method of claim 4051,further comprising supporting at least the one elongated member on acenter support member.
 4056. The method of claim 4051, furthercomprising supporting at least the one elongated member on a centersupport member, wherein the center support member comprises a tube.4057. The method of claim 405l,further comprising electrically isolatingat least the one elongated member with a centralizer.
 4058. The methodof claim 4051,further comprising laterally spacing at least the oneelongated member with a centralizer.
 4059. The method of claim 4051,further comprising electrically coupling at least the one elongatedmember in a series configuration.
 4060. The method of claim 4051,further comprising electrically coupling at least the one elongatedmember in a parallel configuration.
 4061. The method of claim 4051,wherein the provided heat comprises approximately 650 W/m toapproximately 1650 W/m.
 4062. The method of claim 4051, furthercomprising determining a temperature distribution in at least the oneelongated member using an electromagnetic signal provided to at leastthe one elongated member.
 4063. The method of claim 4051, furthercomprising monitoring the applied electrical current.
 4064. The methodof claim 4051, further comprising monitoring a voltage applied to atleast the one elongated member.
 4065. The method of claim 4051, furthercomprising monitoring a temperature in at least the one elongated memberwith at least one thermocouple.
 4066. The method of claim 4051, furthercomprising supporting at least the one elongated member on a centersupport member, wherein the center support member comprises openings,wherein providing the oxidizing fluid to at least the one elongatedmember comprises flowing the oxidizing fluid through the openings in thecenter support member.
 4067. The method of claim 4051, wherein providingthe oxidizing fluid to at least the one elongated member comprisesflowing the oxidizing fluid through orifices in a tube disposed in theopening proximate to at least the one elongated member.
 4068. The methodof claim 4051, further comprising electrically coupling a lead-inconductor to at least the one elongated member, wherein the lead-inconductor comprises a low resistance conductor configured to generatesubstantially no heat.
 4069. The method of claim 4051, furthercomprising electrically coupling a lead-in conductor to at least the oneelongated member using a cold pin transition conductor.
 4070. The methodof claim 4051, further comprising electrically coupling a lead-inconductor to at least the one elongated member using a cold pintransition conductor, wherein the cold pin transition conductorcomprises a substantially low resistance insulated conductor.
 4071. Themethod of claim 4051, further comprising coupling an overburden casingto the opening, wherein the overburden casing is disposed in anoverburden of the formation.
 4072. The method of claim 4051, furthercomprising coupling an overburden casing to the opening, wherein theoverburden casing comprises steel.
 4073. The method of claim 4051,further comprising coupling an overburden casing to the opening, whereinthe overburden casing is disposed in cement.
 4074. The method of claim4051, further comprising coupling an overburden casing to the opening,wherein a packing material is disposed at a junction of the overburdencasing and the opening.
 4075. The method of claim 4051, furthercomprising coupling an overburden casing to the opening, wherein apacking material is disposed at a junction of the overburden casing andthe opening, and wherein the method further comprises inhibiting a flowof fluid between the opening and the overburden casing with the packingmaterial.
 4076. The method of claim 4051, further comprising heating atleast the portion of the formation to substantially pyrolyze at leastsome of the carbon within the formation.
 4077. An in situ method forheating a coal formation, comprising: oxidizing a fuel fluid in aheater; providing at least a portion of the oxidized fuel fluid into aconduit disposed in an opening of the formation; allowing heat totransfer from the oxidized fuel fluid to a section of the formation; andallowing additional heat to transfer from an electric heater disposed inthe opening to the section of the formation, wherein heat is allowed totransfer substantially uniformly along a length of the opening. 4078.The method of claim 4077, wherein providing at least the portion of theoxidized fuel fluid into the opening comprises flowing the oxidized fuelfluid through a perforated conduit disposed in the opening.
 4079. Themethod of claim 4077, wherein providing at least the portion of theoxidized fuel fluid into the opening comprises flowing the oxidized fuelfluid through a perforated conduit disposed in the opening, the methodfurther comprising removing an exhaust fluid through the opening. 4080.The method of claim 4077, further comprising initiating oxidation of thefuel fluid in the heater with a flame.
 4081. The method of claim 4077,further comprising removing the oxidized fuel fluid through the conduit.4082. The method of claim 4077, further comprising removing the oxidizedfuel fluid through the conduit and providing the removed oxidized fuelfluid to at least one additional heater disposed in the formation. 4083.The method of claim 4077, wherein the conduit comprises an insulatordisposed on a surface of the conduit, the method further comprisingtapering a thickness of the insulator such that heat is allowed totransfer substantially uniformly along a length of the conduit. 4084.The method of claim 4077, wherein the electric heater is an insulatedconductor.
 4085. The method of claim 4077, wherein the electric heateris a conductor disposed in the conduit.
 4086. The method of claim 4077,wherein the electric heater is an elongated conductive member.
 4087. Asystem configured to heat a coal formation, comprising: one or more heatsources disposed within one or more open wellbores in the formation,wherein the one or more heat sources are configured to provide heat toat least a portion of the formation during use; and wherein the systemis configured to allow heat to transfer from the one or more heatsources to a selected section of the formation during use.
 4088. Thesystem of claim 4087, wherein the one or more heat sources comprise atleast two heat sources, and wherein superposition of heat from at leastthe two heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 4089. The system of claim 4087,wherein the one or more heat sources comprise electrical heaters. 4090.The system of claim 4087, wherein the one or more heat sources comprisesurface burners.
 4091. The system of claim 4087, wherein the one or moreheat sources comprise flameless distributed combustors.
 4092. The systemof claim 4087, wherein the one or more heat sources comprise naturaldistributed combustors.
 4093. The system of claim 4087, wherein the oneor more open wellbores comprise a diameter of at least approximately 5cm.
 4094. The system of claim 4087, further comprising an overburdencasing coupled to at least one of the one or more open wellbores,wherein the overburden casing is disposed in an overburden of theformation.
 4095. The system of claim 4087, further comprising anoverburden casing coupled to at least one of the one or more openwellbores, wherein the overburden casing is disposed in an overburden ofthe formation, and wherein the overburden casing comprises steel. 4096.The system of claim 4087, further comprising an overburden casingcoupled to at least one of the one or more open wellbores, wherein theoverburden casing is disposed in an overburden of the formation, andwherein the overburden casing is further disposed in cement.
 4097. Thesystem of claim 4087, further comprising an overburden casing coupled toat least one of the one or more open wellbores, wherein the overburdencasing is disposed in an overburden of the formation, and wherein apacking material is disposed at a junction of the overburden casing andthe at least one of the one or more open wellbores.
 4098. The system ofclaim 4087, further comprising an overburden casing coupled to at leastone of the one or more open wellbores, wherein the overburden casing isdisposed in an overburden of the formation, wherein a packing materialis disposed at a junction of the overburden casing and the at least oneof the one or more open wellbores, and wherein the packing material isconfigured to substantially inhibit a flow of fluid between at least oneof the one or more open wellbores and the overburden casing during use.4099. The system of claim 4087, further comprising an overburden casingcoupled to at least one of the one or more open wellbores, wherein theoverburden casing is disposed in an overburden of the formation, whereina packing material is disposed at a junction of the overburden casingand the at least one of the one or more open wellbores, and wherein thepacking material comprises cement.
 4100. The system of claim 4087,wherein the system is further configured to transfer heat such that thetransferred heat can pyrolyze at least some hydrocarbons in the selectedsection.
 4101. The system of claim 4087, further comprising a valvecoupled to at least one of the one or more heat sources configured tocontrol pressure within at least a majority of the selected section ofthe formation.
 4102. The system of claim 4087, further comprising avalve coupled to a production well configured to control a pressurewithin at least a majority of the selected section of the formation.4103. A method of treating a coal formation in situ, comprising:providing heat from one or more heat sources to at least one portion ofthe formation, wherein the one or more heat sources are disposed withinone or more open wellbores in the formation; allowing the heat totransfer from the one or more heat sources to a selected section of theformation; and producing a mixture from the formation.
 4104. The methodof claim 4103, wherein the one or more heat sources comprise at leasttwo heat sources, and wherein superposition of heat from at least thetwo heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation.
 4105. The method of claim 4103,wherein controlling formation conditions comprises maintaining atemperature within the selected section within a pyrolysis temperaturerange with a lower pyrolysis temperature of about 250° C. and an upperpyrolysis temperature of about 400° C.
 4106. The method of claim 4103,wherein the one or more heat sources comprise electrical heaters. 4107.The method of claim 4103, wherein the one or more heat sources comprisesurface burners.
 4108. The method of claim 4103, wherein the one or moreheat sources comprise flameless distributed combustors.
 4109. The methodof claim 4103, wherein the one or more heat sources comprise naturaldistributed combustors.
 4110. The method of claim 4103, wherein the oneor more heat sources are suspended within the one or more openwellbores.
 4111. The method of claim 4103, wherein a tube is disposed inat least one of the one or more open wellbores proximate to heat source,the method further comprising flowing a substantially constant amount afluid into at least one of the one or more open wellbores throughcritical flow orifices in the tube.
 4112. The method of claim 4103,wherein a perforated tube is disposed in at least one of the one or moreopen wellbores proximate to the heat source, the method furthercomprising flowing a corrosion inhibiting fluid into at least one of theopen wellbores through the perforated tube.
 4113. The method of claim4103, further comprising coupling an overburden casing to at least oneof the one or more open wellbores, wherein the overburden casing isdisposed in an overburden of the formation.
 4114. The method of claim4103, further comprising coupling an overburden casing to at least oneof the one or more open wellbores, wherein the overburden casing isdisposed in an overburden of the formation, and wherein the overburdencasing comprise steel.
 4115. The method of claim 4103, furthercomprising coupling an overburden casing to at least one of the one ormore open wellbores, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the overburden casing isfurther disposed in cement.
 4116. The method of claim 4103, furthercomprising coupling an overburden casing to at least one of the one ormore open wellbores, wherein the overburden casing is disposed in anoverburden of the formation, and wherein a packing material is disposedat a junction of the overburden casing and the at least one of the oneor more open wellbores.
 4117. The method of claim 4103, furthercomprising coupling an overburden casing to at least one of the one ormore open wellbores, wherein the overburden casing is disposed in anoverburden of the formation, and wherein the method further comprisesinhibiting a flow of fluid between the at least one of the one or moreopen wellbores and the overburden casing with a packing material. 4118.The method of claim 4103, further comprising heating at least theportion of the formation to substantially pyrolyze at least some of thecarbon within the formation.
 4119. The method of claim 4103, furthercomprising controlling a pressure and a temperature within at least amajority of the selected section of the formation, wherein the pressureis controlled as a function of temperature, or the temperature iscontrolled as a function of pressure.
 4120. The method of claim 4103,further comprising controlling a pressure with the wellbore.
 4121. Themethod of claim 4103, further comprising controlling a pressure withinat least a majority of the selected section of the formation with avalve coupled to at least one of the one or more heat sources.
 4122. Themethod of claim 4103, further comprising controlling a pressure withinat least a majority of the selected section of the formation with avalve coupled to a production well located in the formation.
 4123. Themethod of claim 4103, further comprising controlling the heat such thatan average heating rate of the selected section is less than about 1° C.per day during pyrolysis.
 4124. The method of claim 4103, whereinproviding heat from the one or more heat sources to at least the portionof formation comprises: heating a selected volume (V) of the coalformation from the one or more heat sources, wherein the formation hasan average heat capacity(C_(v)), and wherein the heating pyrolyzes atleast some hydrocarbons within the selected volume of the formation; andwherein heating energy/day provided to the volume is equal to or lessthan Pwr, wherein Pwr is calculated by the equation: Pwr=h*V*C_(v)*ρ_(B) wherein Pwr is the heating energy/day, h is an averageheating rate of the formation, ρ_(B) is formation bulk density, andwherein the heating rate is less than about 10° C./day.
 4125. The methodof claim 4103, wherein allowing the heat to transfer from the one ormore heat sources to the selected section comprises transferring heatsubstantially by conduction.
 4126. The method of claim 4103, whereinproviding heat from the one or more heat sources comprises heating theselected section such that a thermal conductivity of at least a portionof the selected section is greater than about 0.5 W/(m° C.).
 4127. Themethod of claim 4103, wherein the produced mixture comprises condensablehydrocarbons having an API gravity of at least about 25°.
 4128. Themethod of claim 4103, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 0.1% by weight to about 15% by weight ofthe condensable hydrocarbons are olefins.
 4129. The method of claim4103, wherein the produced mixture comprises non-condensablehydrocarbons, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.4130. The method of claim 4103, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein about 0.1% by weight to about15% by weight of the non-condensable hydrocarbons are olefins.
 4131. Themethod of claim 4103, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 1% by weight, when calculatedon an atomic basis, of the condensable hydrocarbons is nitrogen. 4132.The method of claim 4103, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 4133. The method of claim 4103, wherein the produced mixturecomprises condensable hydrocarbons, wherein about 5% by weight to about30% by weight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.4134. The method of claim 4103, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons issulfur.
 4135. The method of claim 4103, wherein the produced mixturecomprises condensable hydrocarbons, and wherein greater than about 20%by weight of the condensable hydrocarbons are aromatic compounds. 4136.The method of claim 4103, wherein the produced mixture comprisescondensable hydrocarbons, and wherein less than about 5% by weight ofthe condensable hydrocarbons comprises multi-ring aromatics with morethan two rings.
 4137. The method of claim 4103, wherein the producedmixture comprises condensable hydrocarbons, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 4138.The method of claim 4103, wherein the produced mixture comprisescondensable hydrocarbons, and wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons are cycloalkanes.
 4139. Themethod of claim 4103, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable componentcomprises hydrogen, and wherein the hydrogen is greater than about 10%by volume of the non-condensable component and wherein the hydrogen isless than about 80% by volume of the non-condensable component. 4140.The method of claim 4103, wherein the produced mixture comprisesammonia, and wherein greater than about 0.05% by weight of the producedmixture is ammonia.
 4141. The method of claim 4103, wherein the producedmixture comprises ammonia, and wherein the ammonia is used to producefertilizer.
 4142. The method of claim 4103, further comprisingcontrolling a pressure within at least a majority of the selectedsection of the formation.
 4143. The method of claim 4103, furthercomprising controlling a pressure within at least a majority of theselected section of the formation, wherein the controlled pressure is atleast about 2.0 bar absolute.
 4144. The method of claim 4103, furthercomprising controlling formation conditions such that the producedmixture comprises a partial pressure of H₂ within the mixture greaterthan about 0.5 bar.
 4145. The method of claim 4144, wherein the partialpressure of H₂ is measured when the mixture is at a production well.4146. The method of claim 4103, wherein controlling formation conditionscomprises recirculating a portion of hydrogen from the mixture into theformation.
 4147. The method of claim 4103, further comprising altering apressure within the formation to inhibit production of hydrocarbons fromthe formation having carbon numbers greater than about
 25. 4148. Themethod of claim 4103, further comprising: providing hydrogen (H₂) to theheated section to hydrogenate hydrocarbons within the section; andheating a portion of the section with heat from hydrogenation.
 4149. Themethod of claim 4103, wherein the produced mixture comprises hydrogenand condensable hydrocarbons, the method further comprisinghydrogenating a portion of the produced condensable hydrocarbons with atleast a portion of the produced hydrogen.
 4150. The method of claim4103, wherein allowing the heat to transfer comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 4151. The method of claim 4103, wherein allowing theheat to transfer comprises substantially uniformly increasing apermeability of a majority of the selected section.
 4152. The method ofclaim 4103, further comprising controlling the heat to yield greaterthan about 60% by weight of condensable hydrocarbons, as measured byFischer Assay.
 4153. The method of claim 4103, wherein producing themixture comprises producing the mixture in a production well, andwherein at least about 7 heat sources are disposed in the formation forthe production well.
 4154. The method of claim 4103, further comprisingproviding heat from three or more heat sources to at least a portion ofthe formation, wherein three or more of the heat sources are located inthe formation in a unit of heat sources, and wherein the unit of heatsources comprises a triangular pattern.
 4155. The method of claim 4103,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, whereinthe unit of heat sources comprises a triangular pattern, and wherein aplurality of the units are repeated over an area of the formation toform a repetitive pattern of units.
 4156. The method of claim 4103,further comprising separating the produced mixture into a gas stream anda liquid stream.
 4157. The method of claim 4103, further comprisingseparating the produced mixture into a gas stream and a liquid streamand separating the liquid stream into an aqueous stream and anon-aqueous stream.
 4158. The method of claim 4103, wherein the producedmixture comprises H₂S, the method further comprising separating aportion of the H₂S from non-condensable hydrocarbons.
 4159. The methodof claim 4103, wherein the produced mixture comprises CO₂, the methodfurther comprising separating a portion of the CO₂ from non-condensablehydrocarbons.
 4160. The method of claim 4103, wherein the mixture isproduced from a production well, wherein the heating is controlled suchthat the mixture can be produced from the formation as a vapor. 4161.The method of claim 4103, wherein the mixture is produced from aproduction well, the method further comprising heating a wellbore of theproduction well to inhibit condensation of the mixture within thewellbore.
 4162. The method of claim 4103, wherein the mixture isproduced from a production well, wherein a wellbore of the productionwell comprises a heater element configured to heat the formationadjacent to the wellbore, and further comprising heating the formationwith the heater element to produce the mixture, wherein the mixturecomprises a large non-condensable hydrocarbon gas component and H₂.4163. The method of claim 4103, wherein the selected section is heatedto a minimum pyrolysis temperature of about 270° C.
 4164. The method ofclaim 4103, further comprising maintaining the pressure within theformation above about 2.0 bar absolute to inhibit production of fluidshaving carbon numbers above
 25. 4165. The method of claim 4103, furthercomprising controlling pressure within the formation in a range fromabout atmospheric pressure to about 100 bar, as measured at a wellheadof a production well, to control an amount of condensable hydrocarbonswithin the produced mixture, wherein the pressure is reduced to increaseproduction of condensable hydrocarbons, and wherein the pressure isincreased to increase production of non-condensable hydrocarbons. 4166.The method of claim 4103, further comprising controlling pressure withinthe formation in a range from about atmospheric pressure to about 100bar, as measured at a wellhead of a production well, to control an APIgravity of condensable hydrocarbons within the produced mixture, whereinthe pressure is reduced to decrease the API gravity, and wherein thepressure is increased to reduce the API gravity.
 4167. A mixtureproduced from a portion of a coal formation, the mixture comprising: anolefin content of less than about 10% by weight; and an average carbonnumber less than about
 35. 4168. The mixture of claim 4167, furthercomprising an average carbon number less than about
 30. 4169. Themixture of claim 4167, further comprising an average carbon number lessthan about
 25. 4170. The mixture of claim 4167, further comprising:non-condensable hydrocarbons comprising hydrocarbons having carbonnumbers of less than 5; and wherein a weight ratio of the hydrocarbonshaving carbon numbers from 2 through 4, to methane, in the mixture isgreater than approximately
 1. 4171. The mixture of claim 4167, furthercomprising condensable hydrocarbons, wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen, wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen, and wherein less than about 1% by weight, when calculated on anatomic basis, of the condensable hydrocarbons is sulfur.
 4172. Themixture of claim 4167, further comprising ammonia, wherein greater thanabout 0.05% by weight of the produced mixture is ammonia.
 4173. Themixture of claim 4167, further comprising condensable hydrocarbons,wherein an olefin content of the condensable hydrocarbons is greaterthan about 0.1% by weight of the condensable hydrocarbons, and whereinthe olefin content of the condensable hydrocarbons is less than about15% by weight of the condensable hydrocarbons.
 4174. The mixture ofclaim 4167, further comprising condensable hydrocarbons, wherein lessthan about 15% by weight of the condensable hydrocarbons have a carbonnumber greater than about
 25. 4175. The mixture of claim 4174, whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen, wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is oxygen, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons issulfur.
 4176. The mixture of claim 4173, further comprising condensablehydrocarbons, wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 4177. The mixture ofclaim 4167, further comprising: non-condensable hydrocarbons comprisinghydrocarbons having carbon numbers of less than about 5, wherein aweight ratio of the hydrocarbons having carbon number from 2 through 4,to methane, in the mixture is greater than approximately 1; wherein thenon-condensable hydrocarbons further comprise H₂, wherein greater thanabout 15% by weight of the non-condensable hydrocarbons comprises H₂;and condensable hydrocarbons, comprising: oxygenated hydrocarbons,wherein greater than about 1.5% by weight of the condensablehydrocarbons comprises oxygenated hydrocarbons; and aromatic compounds,wherein greater than about 20% by weight of the condensable hydrocarbonscomprises aromatic compounds.
 4178. The mixture of claim 4167, furthercomprising: condensable hydrocarbons, wherein less than about 5% byweight of the condensable hydrocarbons comprises hydrocarbons having acarbon number greater than about 25; wherein the condensablehydrocarbons further comprise: oxygenated hydrocarbons, wherein greaterthan about 5% by weight of the condensable hydrocarbons comprisesoxygenated hydrocarbons; and aromatic compounds, wherein greater thanabout 30% by weight of the condensable hydrocarbons comprises aromaticcompounds; and non-condensable hydrocarbons comprising H₂, whereingreater than about 15% by weight of the non-condensable hydrocarbonscomprises H₂.
 4179. The mixture of claim 4167, further comprising acondensable mixture, comprising: olefins, wherein about 0.1% by weightto about 15% by weight of the condensable mixture comprises olefins; andasphaltenes, wherein less than about 0.1% by weight of the condensablemixture comprises asphaltenes.
 4180. The mixture of claim 4179, furthercomprising, oxygenated hydrocarbons, wherein less than about 15% byweight of the condensable mixture comprises oxygenated hydrocarbons;4181. The mixture of claim 4167, further comprising a condensablemixture, comprising: olefins, wherein about 0.1% by weight to about 2%by weight of the condensable mixture comprises olefins; and multi-ringaromatics, wherein less than about 2% by weight of the condensablemixture comprises multi-ring aromatics with more than two rings. 4182.The mixture of claim 4180, further comprising oxygenated hydrocarbons,wherein greater than about 25% by weight of the condensable mixturecomprises oxygenated hydrocarbons.
 4183. The mixture of claim 4167,further comprising: non-condensable hydrocarbons, wherein thenon-condensable hydrocarbons comprise H₂, wherein greater than about 10%by weight of the non-condensable hydrocarbons comprises H₂; ammonia,wherein greater than about 0.5% by weight of the mixture comprisesammonia; and hydrocarbons, wherein a weight ratio of hydrocarbons havinggreater than about 2 carbon atoms, to methane, is greater than about0.4.
 4184. A mixture produced from a portion of a coal formation, themixture, comprising: non-condensable hydrocarbons comprisinghydrocarbons having carbon numbers of less than 5; and wherein a weightratio of the hydrocarbons having carbon numbers from 2 through 4, tomethane, in the mixture is greater than approximately
 1. 4185. Themixture of claim 4184, further comprising condensable hydrocarbons,wherein about 0.1% by weight to about 15% by weight of the condensablehydrocarbons are olefins.
 4186. The mixture of claim 4184, wherein amolar ratio of ethene to ethane in the non-condensable hydrocarbonsranges from about 0.001 to about 0.15.
 4187. The mixture of claim 4184,further comprising condensable hydrocarbons, wherein less than about 1%by weight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 4188. The mixture of claim 4184, furthercomprising condensable hydrocarbons, wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is oxygen.
 4189. The mixture of claim 4184, furthercomprising condensable hydrocarbons, wherein about 5% by weight to about30% by weight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.4190. The mixture of claim 4184, further comprising condensablehydrocarbons, wherein less than about 1% by weight, when calculated onan atomic basis, of the condensable hydrocarbons is sulfur.
 4191. Themixture of claim 4184, further comprising condensable hydrocarbons,wherein greater than about 20% by weight of the condensable hydrocarbonsare aromatic compounds.
 4192. The mixture of claim 4184, furthercomprising condensable hydrocarbons, wherein less than about 5% byweight of the condensable hydrocarbons comprises multi-ring aromaticswith more than two rings.
 4193. The mixture of claim 4184, furthercomprising condensable hydrocarbons, wherein less than about 0.3% byweight of the condensable hydrocarbons are asphaltenes.
 4194. Themixture of claim 4184, further comprising condensable hydrocarbons,wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons comprise cycloalkanes.
 4195. The mixture of claim 4184,wherein the non-condensable hydrocarbons further comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable hydrocarbons, and wherein the hydrogen is less thanabout 80% by volume of the non-condensable hydrocarbons.
 4196. Themixture of claim 4184, further comprising ammonia, wherein greater thanabout 0.05% by weight of the produced mixture is ammonia.
 4197. Themixture of claim 4184, further comprising ammonia, wherein the ammoniais used to produce fertilizer.
 4198. The mixture of claim 4184, furthercomprising condensable hydrocarbons, wherein less than about 15 weight %of the condensable hydrocarbons have a carbon number greater thanapproximately
 25. 4199. The mixture of claim 4184, further comprisingcondensable hydrocarbons, wherein the condensable hydrocarbons compriseolefins, and wherein about 0.1% to about 5% by weight of the condensablehydrocarbons comprises olefins.
 4200. The mixture of claim 4184, furthercomprising condensable hydrocarbons, wherein the condensablehydrocarbons comprises olefins, and wherein about 0.1% to about 2.5% byweight of the condensable hydrocarbons comprises olefins.
 4201. Themixture of claim 4184, further comprising condensable hydrocarbons,wherein the condensable hydrocarbons comprise oxygenated hydrocarbons,and wherein greater than about 5% by weight of the condensablehydrocarbons comprises oxygenated hydrocarbons.
 4202. The mixture ofclaim 4184, further comprising non-condensable hydrocarbons, wherein thenon-condensable hydrocarbons comprise H₂, and wherein greater than about5% by weight of the non-condensable hydrocarbons comprises H₂.
 4203. Themixture of claim 4184, further comprising non-condensable hydrocarbons,wherein the non-condensable hydrocarbons comprise H₂, and whereingreater than about 15% by weight of the non-condensable hydrocarbonscomprises H₂.
 4204. The mixture of claim 4184, where in a weight ratioof hydrocarbons having greater than about 2 carbon atoms, to methane, isgreater than about 0.3.
 4205. A mixture produced from a portion of acoal formation, the mixture comprising: non-condensable hydrocarbonscomprising hydrocarbons having carbon numbers of less than 5, wherein aweight ratio of hydrocarbons having carbon numbers from 2 through 4, tomethane, is greater than approximately 1; and condensable hydrocarbonscomprising oxygenated hydrocarbons, wherein greater than about 5% byweight of the condensable component comprises oxygenated hydrocarbons.4206. The mixture of claim 4205, wherein about 0.1% by weight to about15% by weight of the condensable hydrocarbons are olefins.
 4207. Themixture of claim 4205, wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.4208. The mixture of claim 4205, wherein less than about 1% by weight,when calculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 4209. The mixture of claim 4205, wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is oxygen.
 4210. The mixture of claim 4205, wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 4211. The mixture of claim 4205,wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons comprise oxygen containing compounds, and wherein theoxygen containing compounds comprise phenols.
 4212. The mixture of claim4205, wherein greater than about 20% by weight of the condensablehydrocarbons are aromatic compounds.
 4213. The mixture of claim 4205,wherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 4214. Themixture of claim 4205, wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 4215. The mixture of claim4205, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons are cycloalkanes.
 4216. The mixture of claim4205, wherein the non-condensable hydrocarbons comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable hydrocarbons, and wherein the hydrogen is less thanabout 80% by volume of the non-condensable hydrocarbons.
 4217. Themixture of claim 4205, wherein the produced mixture comprises ammonia,and wherein greater than about 0.05% by weight of the produced mixtureis ammonia.
 4218. The mixture of claim 4205, wherein the producedmixture comprises ammonia, and wherein the ammonia is used to producefertilizer.
 4219. The mixture of claim 4205, wherein less than about 5weight % of the condensable hydrocarbons in the mixture have a carbonnumber greater than approximately
 25. 4220. The mixture of claim 4205,wherein the condensable hydrocarbons further comprise olefins, andwherein about 0.1% to about 5% by weight of the condensable hydrocarbonscomprises olefins.
 4221. The mixture of claim 4205, wherein thecondensable hydrocarbons further comprise olefins, and wherein about0.1% to about 2.5% by weight of the condensable hydrocarbons comprisesolefins.
 4222. The mixture of claim 4205, wherein the non-condensablehydrocarbons further comprise H₂, wherein greater than about 5% byweight of the mixture comprises H₂.
 4223. The mixture of claim 4205,wherein the non-condensable hydrocarbons further comprise H₂, whereingreater than about 15% by weight of the mixture comprises H₂.
 4224. Themixture of claim 4205, wherein a weight ratio of hydrocarbons havinggreater than about 2 carbon atoms, to methane, is greater than about0.3.
 4225. A mixture produced from a portion of a coal formation, themixture comprising: non-condensable hydrocarbons comprising hydrocarbonshaving carbon numbers of less than 5, wherein a weight ratio ofhydrocarbons having carbon numbers from 2 through 4, to methane, isgreater than approximately 1; condensable hydrocarbons; wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons comprises nitrogen; wherein less than about 1%by weight, when calculated on an atomic basis, of the condensablehydrocarbons comprises oxygen; and wherein less than about 1% by weight,when calculated on an atomic basis, of the condensable hydrocarbonscomprises sulfur.
 4226. The mixture of claim 4225, further comprisingammonia, wherein greater than about 0.05% by weight of the producedmixture is ammonia.
 4227. The mixture of claim 4225, wherein less thanabout 5 weight % of the condensable hydrocarbons have a carbon numbergreater than approximately
 25. 4228. The mixture of claim 4225, whereinthe condensable hydrocarbons comprise olefins, and wherein about 0.1% byweight to about 15% by weight of the condensable hydrocarbons areolefins.
 4229. The mixture of claim 4225, wherein a molar ratio ofethene to ethane in the non-condensable hydrocarbons ranges from about0.001 to about 0.15.
 4230. The mixture of claim 4225, wherein about 5%by weight to about 30% by weight of the condensable hydrocarbonscomprise oxygen containing compounds, and wherein the oxygen containingcompounds comprise phenols.
 4231. The mixture of claim 4225, whereingreater than about 20% by weight of the condensable hydrocarbons arearomatic compounds.
 4232. The mixture of claim 4225, wherein less thanabout 5% by weight of the condensable hydrocarbons comprises multi-ringaromatics with more than two rings.
 4233. The mixture of claim 4225,wherein less than about 0.3% by weight of the condensable hydrocarbonsare asphaltenes.
 4234. The mixture of claim 4225, wherein about 5% byweight to about 30% by weight of the condensable hydrocarbons arecycloalkanes.
 4235. The mixture of claim 4225, wherein thenon-condensable hydrocarbons comprises hydrogen, and wherein thehydrogen is greater than about 10% by volume of the non-condensablehydrocarbons and wherein the hydrogen is less than about 80% by volumeof the non-condensable hydrocarbons.
 4236. The mixture of claim 4225,further comprising ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 4237. The mixture of claim4225, further comprising ammonia, and wherein the ammonia is used toproduce fertilizer.
 4238. The mixture of claim 4225, wherein thecondensable hydrocarbons comprises oxygenated hydrocarbons, and whereingreater than about 5% by weight of the condensable component comprisesoxygenated hydrocarbons.
 4239. The mixture of claim 4225, wherein thenon-condensable hydrocarbons comprise H₂, and wherein greater than about5% by weight of the non-condensable hydrocarbons comprises H₂.
 4240. Themixture of claim 4225, wherein the non-condensable hydrocarbons compriseH₂, and wherein greater than about 15% by weight of the mixturecomprises H₂.
 4241. The mixture of claim 4225, wherein a weight ratio ofhydrocarbons having greater than about 2 carbon atoms, to methane, isgreater, than about 0.3.
 4242. A mixture produced from a portion of acoal formation, the mixture comprising: non-condensable hydrocarbonscomprising hydrocarbons having carbon numbers of less than 5, wherein aweight ratio of hydrocarbons having carbon numbers from 2 through 4, tomethane, is greater than approximately 1; ammonia, wherein greater thanabout 0.5% by weight of the mixture comprises ammonia; and condensablehydrocarbons comprising oxygenated hydrocarbons, wherein greater thanabout 5% by weight of the condensable hydrocarbons comprises oxygenatedhydrocarbons.
 4243. The mixture of claim 4242, wherein the condensablehydrocarbons further comprise olefins, and wherein about 0.1% by weightto about 15% by weight of the condensable hydrocarbons are olefins.4244. The mixture of claim 4242, wherein the non-condensablehydrocarbons further comprise ethene and ethane, and wherein a molarratio of ethene to ethane in the non-condensable hydrocarbons rangesfrom about 0.001 to about 0.15.
 4245. The mixture of claim 4242, whereinthe condensable hydrocarbons further comprise nitrogen, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 4246. The mixture of claim 4242,wherein the condensable hydrocarbons further comprise oxygen, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the, condensable hydrocarbons is oxygen.
 4247. The mixture ofclaim 4242, wherein the condensable hydrocarbons further comprisesulfur, and wherein less than about 1% by weight, when calculated on anatomic basis, of the condensable hydrocarbons is sulfur.
 4248. Themixture of claim 4242, wherein the condensable hydrocarbons furthercomprise oxygen containing compounds, wherein about 5% by weight toabout 30% by weight of the condensable hydrocarbons comprise oxygencontaining compounds, and wherein the oxygen containing compoundscomprise phenols.
 4249. The mixture of claim 4242, wherein thecondensable hydrocarbons further comprise aromatic compounds, andwherein greater than about 20% by weight of the condensable hydrocarbonsare aromatic compounds.
 4250. The mixture of claim 4242, wherein thecondensable hydrocarbons further comprise multi-aromatic rings, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 4251. Themixture of claim 4242, wherein the condensable hydrocarbons furthercomprise asphaltenes, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 4252. The mixture of claim4242, wherein the condensable hydrocarbons further comprisecycloalkanes, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 4253. The mixture ofclaim 4242, wherein the non-condensable hydrocarbons further comprisehydrogen, wherein the hydrogen is greater than about 10% by volume ofthe non-condensable hydrocarbons, and wherein the hydrogen is less thanabout 80% by volume of the non-condensable hydrocarbons.
 4254. Themixture of claim 4242, wherein the produced mixture further comprisesammonia, and wherein greater than about 0.05% by weight of the producedmixture is ammonia.
 4255. The mixture of claim 4242, wherein theproduced mixture further comprises ammonia, and wherein the ammonia isused to produce fertilizer.
 4256. The mixture of claim 4242, wherein thecondensable hydrocarbons comprise hydrocarbons having a carbon number ofgreater than approximately 25, and wherein less than about 15 weight %of the hydrocarbons in the mixture have a carbon number greater thanapproximately
 25. 4257. The mixture of claim 4242, wherein thenon-condensable hydrocarbons further comprise H₂, and wherein greaterthan about 5% by weight of the mixture comprises H₂.
 4258. The mixtureof claim 4242, wherein the non-condensable hydrocarbons further compriseH₂, and wherein greater than about 15% by weight of the mixturecomprises H₂.
 4259. The mixture of claim 4242, wherein thenon-condensable hydrocarbons further comprise hydrocarbons having carbonnumbers of greater than 2, wherein a weight ratio of hydrocarbons havingcarbon numbers greater than 2, to methane, is greater than about 0.3.4260. A mixture produced from a portion of a coal formation, the mixturecomprising: non-condensable hydrocarbons comprising hydrocarbons havingcarbon numbers of less than 5, wherein a weight ratio of hydrocarbonshaving carbon numbers from 2 through 4, to methane, is greater thanapproximately 1; and condensable hydrocarbons comprising olefins,wherein less than about 10% by weight of the condensable hydrocarbonscomprises olefins.
 4261. The mixture of claim 4260, wherein thenon-condensable hydrocarbons further comprise ethene and ethane, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 4262. The mixture ofclaim 4260, wherein the condensable hydrocarbons further comprisenitrogen, and wherein less than about 1% by weight, when calculated onan atomic basis, of the condensable hydrocarbons is nitrogen.
 4263. Themixture of claim 4260, wherein the condensable hydrocarbons furthercomprise oxygen, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 4264. The mixture of claim 4260, wherein the condensablehydrocarbons further comprise sulfur, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 4265. The mixture of claim 4260, wherein thecondensable hydrocarbons further comprise oxygen containing compounds,wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons comprise oxygen containing compounds, and wherein theoxygen containing compounds comprise phenols.
 4266. The mixture of claim4260, wherein the condensable hydrocarbons further comprise aromaticcompounds, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 4267. The mixture ofclaim 4260, wherein the condensable hydrocarbons further comprisemulti-ring aromatics, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 4268. The mixture of claim 4260, wherein the condensablehydrocarbons further comprise asphaltenes, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 4269.The mixture of claim 4260, wherein the condensable hydrocarbons furthercomprise cycloalkanes, and wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons are cycloalkanes.
 4270. Themixture of claim 4260, wherein the non-condensable hydrocarbons furthercomprise hydrogen, and wherein the hydrogen is greater than about 10% byvolume of the non-condensable hydrocarbons and wherein the hydrogen isless than about 80% by volume of the non-condensable hydrocarbons. 4271.The mixture of claim 4260, wherein the produced mixture furthercomprises ammonia, and wherein greater than about 0.05% by weight of theproduced mixture is ammonia.
 4272. The mixture of claim 4260, whereinthe produced mixture further comprises ammonia, and wherein the ammoniais used to produce fertilizer.
 4273. The mixture of claim 4260, whereinthe condensable hydrocarbons further comprise hydrocarbons having acarbon number of greater than approximately 25, and wherein less thanabout 15% by weight of the hydrocarbons have a carbon number greaterthan approximately
 25. 4274. The mixture of claim 4260, wherein about0.1% to about 5% by weight of the condensable component comprisesolefins.
 4275. The mixture of claim 4260, wherein about 0.1% to about 2%by weight of the condensable component comprises olefins.
 4276. Themixture of claim 4260, wherein the condensable hydrocarbons furthercomprise oxygenated hydrocarbons, and wherein greater than about 5% byweight of the condensable hydrocarbons comprises oxygenatedhydrocarbons.
 4277. The mixture of claim 4260, wherein the condensablehydrocarbons further comprise oxygenated hydrocarbons, and whereingreater than about 25% by weight of the condensable component comprisesoxygenated hydrocarbons.
 4278. The mixture of claim 4260, wherein thenon-condensable hydrocarbons further comprise H₂, and wherein greaterthan about 5% by weight of the non-condensable hydrocarbons comprisesH₂.
 4279. The mixture of claim 4260, wherein the non-condensablehydrocarbons further comprise H₂, and wherein greater than about 15% byweight of the non-condensable hydrocarbons comprises H₂.
 4280. Themixture of claim 4260, wherein a weight ratio of hydrocarbons havinggreater than about 2 carbon atoms, to methane, is greater than about0.3.
 4281. A mixture produced from a portion of a coal formation,comprising: condensable hydrocarbons, wherein less than about 15 weight% of the condensable hydrocarbons have a carbon number greater than 25;and wherein the condensable hydrocarbons comprise oxygenatedhydrocarbons, and wherein greater than about 5% by weight of thecondensable hydrocarbons comprises oxygenated hydrocarbons.
 4282. Themixture of claim 4281, further comprising non-condensable hydrocarbons,wherein the non-condensable hydrocarbons comprise hydrocarbons havingcarbon numbers of less than 5, and wherein a weight ratio ofhydrocarbons having carbon numbers from 2 through 4, to methane, isgreater than approximately
 1. 4283. The mixture of claim 4281, whereinthe condensable hydrocarbons further comprise olefins, and wherein about0.1% by weight to about 15% by weight of the condensable hydrocarbonsare olefins.
 4284. The mixture of claim 4281, further comprisingnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons ranges from about 0.001 to about0.15.
 4285. The mixture of claim 4281, wherein the condensablehydrocarbons further comprise nitrogen, and wherein less than about 1%by weight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 4286. The mixture of claim 4281, wherein thecondensable hydrocarbons further comprise oxygen, and wherein less thanabout 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 4287. The mixture of claim 4281,wherein the condensable hydrocarbons further comprise sulfur, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 4288. The mixture ofclaim 4281, wherein the condensable hydrocarbons further comprise oxygencontaining compounds, wherein about 5% by weight to about 30% by weightof the condensable hydrocarbons comprise oxygen containing compounds,and wherein the oxygen containing compounds comprise phenols.
 4289. Themixture of claim 4281, wherein the condensable hydrocarbons furthercomprise aromatic compounds, and wherein greater than about 20% byweight of the condensable hydrocarbons are aromatic compounds.
 4290. Themixture of claim 4281, wherein the condensable hydrocarbons furthercomprise multi-ring aromatics, and wherein less than about 5% by weightof the condensable hydrocarbons comprises multi-ring aromatics with morethan two rings.
 4291. The mixture of claim 4281, wherein the condensablehydrocarbons further comprise asphaltenes, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 4292.The mixture of claim 4281, wherein the condensable hydrocarbons furthercomprise cycloalkanes, and wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons are cycloalkanes.
 4293. Themixture of claim 4281, further comprising non-condensable hydrocarbons,wherein the non-condensable hydrocarbons comprise hydrogen, and whereinthe hydrogen is greater than about 10% by volume of the non-condensablehydrocarbons and wherein the hydrogen is less than about 80% by volumeof the non-condensable hydrocarbons.
 4294. The mixture of claim 4281,further comprising ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 4295. The mixture of claim4281, further comprising ammonia, and wherein the ammonia is used toproduce fertilizer.
 4296. The mixture of claim 4281, wherein thecondensable hydrocarbons further comprises olefins, and wherein lessthan about 10% by weight of the condensable hydrocarbons comprisesolefins.
 4297. The mixture of claim 4281, wherein the condensablehydrocarbons further comprises olefins, and wherein about 0.1% to about5% by weight of the condensable hydrocarbons comprises olefins. 4298.The mixture of claim 4281, wherein the condensable hydrocarbons furthercomprises olefins, and wherein about 0.1% to about 2% by weight of thecondensable hydrocarbons comprises olefins.
 4299. The mixture of claim4281, wherein the condensable hydrocarbons further comprises oxygenatedhydrocarbons, and wherein greater than about 5% by weight of thecondensable hydrocarbons comprises the oxygenated hydrocarbon.
 4300. Themixture of claim 4281, further comprising non-condensable hydrocarbons,wherein the non-condensable hydrocarbons comprise H₂, wherein greaterthan about 5% by weight of the non-condensable hydrocarbons comprisesH₂.
 4301. The mixture of claim 4281, further comprising non-condensablehydrocarbons, wherein the non-condensable hydrocarbons comprise H₂,wherein greater than about 15% by weight of the non-condensablehydrocarbons comprises H₂.
 4302. The mixture of claim 4281, wherein aweight ratio of hydrocarbons having greater than about 2 carbon atoms,to methane, is greater than about 0.3.
 4303. A mixture produced from aportion of a coal formation, comprising: condensable hydrocarbons,wherein less than about 15% by weight of the condensable hydrocarbonshave a carbon number greater than about 25; wherein less than about 1%by weight of the condensable hydrocarbons, when calculated on an atomicbasis, is nitrogen; wherein less than about 1% by weight of thecondensable hydrocarbons, when calculated on an atomic basis, is oxygen;and wherein less than about 1% by weight of the condensablehydrocarbons, when calculated on an atomic basis, is sulfur.
 4304. Themixture of claim 4303, further comprising non-condensable hydrocarbons,wherein the non-condensable component comprises hydrocarbons havingcarbon numbers of less than 5, and wherein a weight ratio ofhydrocarbons having carbon numbers from 2 through 4, to methane, isgreater than approximately
 1. 4305. The mixture of claim 4303, whereinthe condensable hydrocarbons further comprise olefins, and wherein about0.1% by weight to about 15% by weight of the condensable hydrocarbonsare olefins.
 4306. The mixture of claim 4303, further comprisingnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 4307. The mixture of claim 4303, wherein the condensablehydrocarbons further comprise oxygen containing compounds; wherein about5% by weight to about 30% by weight of the condensable hydrocarbonscomprise oxygen containing compounds, and wherein the oxygen containingcompounds comprise phenols.
 4308. The mixture of claim 4303, wherein thecondensable hydrocarbons further comprise aromatic compounds, andwherein greater than about 20% by weight of the condensable hydrocarbonsare aromatic compounds.
 4309. The mixture of claim 4303, wherein thecondensable hydrocarbons further comprise multi-ring aromatics, andwherein less than about 5% by weight of the condensable hydrocarbonscomprises multi-ring aromatics with more than two rings.
 4310. Themixture of claim 4303, wherein the condensable hydrocarbons furthercomprise asphaltenes, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 4311. The mixture of claim4303, wherein the condensable hydrocarbons further comprisecycloalkanes, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 4312. The mixture ofclaim 4303, further comprising non-condensable hydrocarbons, and whereinthe non-condensable hydrocarbons comprise hydrogen, and wherein greaterthan about 10% by volume and less than about 80% by volume of thenon-condensable component comprises hydrogen.
 4313. The mixture of claim4303, further comprising ammonia, and wherein greater than about 0.05%by weight of the produced mixture is ammonia.
 4314. The mixture of claim4303, further comprising ammonia, and wherein the ammonia is used toproduce fertilizer.
 4315. The mixture of claim 4303, wherein thecondensable component further comprises olefins, and wherein about 0.1%to about 5% by weight of the condensable component comprises olefins.4316. The mixture of claim 4303, wherein the condensable componentfurther comprises olefins, and wherein about 0.1% to about 2.5% byweight of the condensable component comprises olefins.
 4317. The mixtureof claim 4303, wherein the condensable hydrocarbons further compriseoxygenated hydrocarbons, and wherein greater than about 5% by weight ofthe condensable hydrocarbons comprises oxygenated hydrocarbons. 4318.The mixture of claim 4303, further comprising non-condensablehydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, andwherein greater than about 5% by weight of the non-condensablehydrocarbons comprises H₂.
 4319. The mixture of claim 4303, furthercomprising non-condensable hydrocarbons, wherein the non-condensablehydrocarbons comprise H₂, and wherein greater than about 15% by weightof the non-condensable hydrocarbons comprises H₂.
 4320. The mixture ofclaim 4303, further comprising non-condensable hydrocarbons, wherein aweight ratio of compounds within the non-condensable hydrocarbons havinggreater than about 2 carbon atoms, to methane, is greater than about0.3.
 4321. A mixture produced from a portion of a coal formation,comprising: condensable hydrocarbons, wherein less than about 15% byweight of the condensable hydrocarbons have a carbon number greater than20; and wherein the condensable hydrocarbons comprise olefins, whereinan olefin content of the condensable component is less than about 10% byweight of the condensable component.
 4322. The mixture of claim 4321,further comprising non-condensable hydrocarbons, wherein thenon-condensable hydrocarbons comprise hydrocarbons having carbon numbersof less than 5, and wherein a weight ratio of hydrocarbons having carbonnumbers from 2 through 4, to methane, is greater than approximately 1.4323. The mixture of claim 4321, wherein the condensable hydrocarbonsfurther comprise olefins, and wherein about 0.1% by weight to about 15%by weight of the condensable hydrocarbons are olefins.
 4324. The mixtureof claim 4321, further comprising non-condensable hydrocarbons, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 4325. The mixture ofclaim 4321, wherein the condensable hydrocarbons further comprisenitrogen, and wherein less than about 1% by weight, when calculated onan atomic basis, of the condensable hydrocarbons is nitrogen.
 4326. Themixture of claim 4321, wherein the condensable hydrocarbons furthercomprise oxygen, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 4327. The mixture of claim 4321, wherein the condensablehydrocarbons further comprise sulfur, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 4328. The mixture of claim 4321, wherein thecondensable hydrocarbons, wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons comprise oxygen containingcompounds, and wherein the oxygen containing compounds comprise phenols.4329. The mixture of claim 4321, wherein the condensable hydrocarbonsfurther comprise aromatic compounds, and wherein greater than about 20%by weight of the condensable hydrocarbons are aromatic compounds. 4330.The mixture of claim 4321, wherein the condensable hydrocarbons furthercomprise multi-ring aromatics, and wherein less than about 5% by weightof the condensable hydrocarbons comprises multi-ring aromatics with morethan two rings.
 4331. The mixture of claim 4321, wherein the condensablehydrocarbons further comprise asphaltenes, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 4332.The mixture of claim 4321, wherein the condensable hydrocarbons furthercomprise cycloalkanes, and wherein about 5% by weight to about 30% byweight of the condensable hydrocarbons are cycloalkanes.
 4333. Themixture of claim 4321, further comprising non-condensable hydrocarbons,wherein the non-condensable hydrocarbons comprises hydrogen, and whereinthe hydrogen is about 10% by volume to about 80% by volume of thenon-condensable hydrocarbons.
 4334. The mixture of claim 4321, furthercomprising ammonia, wherein greater than about 0.05% by weight of theproduced mixture is ammonia.
 4335. The mixture of claim 4321, furthercomprising ammonia, and wherein the ammonia is used to producefertilizer.
 4336. The mixture of claim 4321, wherein about 0.1% to about5% by weight of the condensable component comprises olefins.
 4337. Themixture of claim 4321, wherein about 0.1% to about 2% by weight of thecondensable component comprises olefins.
 4338. The mixture of claim4321, wherein the condensable component further comprises oxygenatedhydrocarbons, and wherein greater than about 1.5% by weight of thecondensable component comprises oxygenated hydrocarbons.
 4339. Themixture of claim 4321, wherein the condensable component furthercomprises oxygenated hydrocarbons, and wherein greater than about 25% byweight of the condensable component comprises oxygenated hydrocarbons.4340. The mixture of claim 4321, further comprising non-condensablehydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, andwherein greater than about 5% by weight of the non-condensablehydrocarbons comprises H₂.
 4341. The mixture of claim 4321, furthercomprising non-condensable hydrocarbons, wherein the non-condensablehydrocarbons comprise H₂, and wherein greater than about 15% by weightof the non-condensable hydrocarbons comprises H₂.
 4342. The mixture ofclaim 4321, further comprising non-condensable hydrocarbons, wherein thenon-condensable hydrocarbons comprise hydrocarbons having carbon numbersof less than 5, and wherein a weight ratio of hydrocarbons having carbonnumbers from 2 through 4, to methane, is greater than approximately 0.3.4343. A mixture produced from a portion of a coal formation, comprising:condensable hydrocarbons, wherein less than about 5% by weight of thecondensable hydrocarbons comprises hydrocarbons having a carbon numbergreater than about 25; and wherein the condensable hydrocarbons furthercomprise aromatic compounds, wherein more than about 20% by weight ofthe condensable hydrocarbons comprises aromatic compounds.
 4344. Themixture of claim 4343, further comprising non-condensable hydrocarbons,wherein the non-condensable hydrocarbons comprise hydrocarbons havingcarbon numbers of less than 5, and wherein a weight ratio ofhydrocarbons having carbon numbers from 2 through 4, to methane, isgreater than approximately
 1. 4345. The mixture of claim 4343, whereinthe condensable hydrocarbons further comprise olefins, and wherein about0.1% by weight to about 15% by weight of the condensable hydrocarbonsare olefins.
 4346. The mixture of claim 4343, further comprisingnon-condensable hydrocarbons, wherein a molar ratio of ethene to ethanein the non-condensable hydrocarbons ranges from about 0.001 to about0.15.
 4347. The mixture of claim 4343, wherein the condensablehydrocarbons further comprise nitrogen, and wherein less than about 1%by weight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 4348. The mixture of claim 4343, wherein thecondensable hydrocarbons further comprise oxygen, and wherein less thanabout 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 4349. The mixture of claim 4343,wherein the condensable hydrocarbons further comprise sulfur, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 4350. The mixture ofclaim 4343, wherein the condensable hydrocarbons further comprise oxygencontaining compounds, wherein about 5% by weight to about 30% by weightof the condensable hydrocarbons comprise oxygen containing compounds,and wherein the oxygen containing compounds comprise phenols.
 4351. Themixture of claim 4343, wherein the condensable hydrocarbons furthercomprise multi-ring aromatics, and wherein less than about 5% by weightof the condensable hydrocarbons comprises multi-ring aromatics with morethan two rings.
 4352. The mixture of claim 4343, wherein the condensablehydrocarbons further comprise asphaltenes, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 4353.The mixture of claim 4343, wherein the condensable hydrocarbons comprisecycloalkanes, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 4354. The mixture ofclaim 4343, further comprising non-condensable hydrocarbons, wherein thenon-condensable hydrocarbons comprise hydrogen, and wherein the hydrogenis greater than about 10% by volume and less than about 80% by volume ofthe non-condensable hydrocarbons.
 4355. The mixture of claim 4343,further comprising ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 4356. The mixture of claim4343, further comprising ammonia, and wherein the ammonia is used toproduce fertilizer.
 4357. The mixture of claim 4343, wherein thecondensable hydrocarbons further comprise olefins, and wherein about0.1% to about 5% by weight of the condensable hydrocarbons comprisesolefins.
 4358. The mixture of claim 4343, wherein the condensablehydrocarbons further comprises olefins, and wherein about 0.1% to about2% by weight of the condensable hydrocarbons comprises olefins. 4359.The mixture of claim 4343, wherein the condensable hydrocarbons furthercomprises multi-ring aromatic compounds, and wherein less than about 2%by weight of the condensable hydrocarbons comprises multi-ring aromaticcompounds.
 4360. The mixture of claim 4343, wherein the condensablehydrocarbons comprises oxygenated hydrocarbons, and wherein greater thanabout 1.5% by weight of the condensable hydrocarbons comprisesoxygenated hydrocarbons.
 4361. The mixture of claim 4343, wherein thecondensable hydrocarbons comprises oxygenated hydrocarbons, and whereingreater than about 25% by weight of the condensable component comprisesoxygenated hydrocarbons.
 4362. The mixture of claim 4343, furthercomprising non-condensable hydrocarbons, wherein the non-condensablehydrocarbons comprise H₂, and wherein greater than about 5% by weight ofthe non-condensable hydrocarbons comprises H₂.
 4363. The mixture ofclaim 4343, further comprising non-condensable hydrocarbons, wherein thenon-condensable hydrocarbons comprise H₂, and wherein greater than about15% by weight of the non-condensable hydrocarbons comprises H₂. 4364.The mixture of claim 4343, further comprising non-condensablehydrocarbons, wherein the non-condensable hydrocarbons compriseshydrocarbons having carbon numbers of less than 5, and wherein a weightratio of hydrocarbons having carbon numbers from 2 through 4, tomethane, is greater than approximately 0.3.
 4365. A mixture producedfrom a portion of a coal formation, comprising: non-condensablehydrocarbons comprising hydrocarbons having carbon numbers of less thanabout 5, wherein a weight ratio of the hydrocarbons having carbon numberfrom 2 through 4, to methane, in the mixture is greater thanapproximately 1; wherein the non-condensable hydrocarbons furthercomprise H₂, wherein greater than about 15% by weight of thenon-condensable hydrocarbons comprises H₂; and condensable hydrocarbons,comprising: oxygenated hydrocarbons, wherein greater than about 1.5% byweight of the condensable hydrocarbons comprises oxygenatedhydrocarbons; olefins, wherein less than about 10% by weight of thecondensable hydrocarbons comprises olefins; and aromatic compounds,wherein greater than about 20% by weight of the condensable hydrocarbonscomprises aromatic compounds.
 4366. The mixture of claim 4365, whereinthe non-condensable hydrocarbons further comprise ethene and ethane, andwherein a molar ratio of ethene to ethane in the non-condensablehydrocarbons ranges from about 0.001 to about 0.15.
 4367. The mixture ofclaim 4365, wherein the condensable hydrocarbons further comprisenitrogen, and wherein less than about 1% by weight, when calculated onan atomic basis, of the condensable hydrocarbons is nitrogen.
 4368. Themixture of claim 4365, wherein the condensable hydrocarbons furthercomprise oxygen, and wherein less than about 1% by weight, whencalculated on an atomic basis, of the condensable hydrocarbons isoxygen.
 4369. The mixture of claim 4365, wherein the condensablehydrocarbons further comprise sulfur, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is sulfur.
 4370. The mixture of claim 4365, wherein thecondensable hydrocarbons further comprise oxygen containing compounds,wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons comprise oxygen containing compounds, and wherein theoxygen containing compounds comprise phenols.
 4371. The mixture of claim4365, wherein the condensable hydrocarbons comprise multi-ringaromatics, and wherein less than about 5% by weight of the condensablehydrocarbons comprises multi-ring aromatics with more than two rings.4372. The mixture of claim 4365, wherein the condensable hydrocarbonscomprise asphaltenes, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 4373. The mixture of claim4365, wherein the condensable hydrocarbons comprise cycloalkanes, andwherein about 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 4374. The mixture of claim 4365, whereinthe non-condensable hydrocarbons further comprises hydrogen, and whereingreater than about 10% by volume and less than about 80% by volume ofthe non-condensable hydrocarbons.
 4375. The mixture of claim 4365,further comprising ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 4376. The mixture of claim4365, further comprising ammonia, and wherein the ammonia is used toproduce fertilizer.
 4377. The mixture of claim 4365, wherein thecondensable hydrocarbons further comprise hydrocarbons having a carbonnumber of greater than approximately 25, wherein less than about 15% byweight of the hydrocarbons have a carbon number greater thanapproximately
 25. 4378. The mixture of claim 4365, wherein about 0.1% toabout 5% by weight of the condensable hydrocarbons comprises olefins.4379. The mixture of claim 4365, wherein about 0.1% to about 2% byweight of the condensable hydrocarbons comprises olefins.
 4380. Themixture of claim 4365, wherein greater than about 25% by weight of thecondensable hydrocarbons comprises oxygenated hydrocarbons.
 4381. Themixture of claim 4365, wherein the mixture comprises hydrocarbons havinggreater than about 2 carbon atoms, and wherein the weight ratio ofhydrocarbons having greater than about 2 carbon atoms to methane isgreater than about 0.3.
 4382. A mixture produced from a portion of acoal formation, comprising: condensable hydrocarbons, wherein less thanabout 5% by weight of the condensable hydrocarbons compriseshydrocarbons having a carbon number greater than about 25; wherein thecondensable hydrocarbons further comprise: oxygenated hydrocarbons,wherein greater than about 5% by weight of the condensable hydrocarbonscomprises oxygenated hydrocarbons; olefins, wherein less than about 10%by weight of the condensable hydrocarbons comprises olefins; andaromatic compounds, wherein greater than about 30% by weight of thecondensable hydrocarbons comprises aromatic compounds; andnon-condensable hydrocarbons comprising H₂, wherein greater than about15% by weight of the non-condensable hydrocarbons comprises H₂. 4383.The mixture of claim 4382, wherein the non-condensable hydrocarbonsfurther comprises hydrocarbons having carbon numbers of less than 5, andwherein a weight ratio of hydrocarbons having carbon numbers from 2through 4, to methane, is greater than approximately
 1. 4384. Themixture of claim 4382, wherein the non-condensable hydrocarbons compriseethene and ethane, and wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons ranges from about 0.001 to about 0.15.4385. The mixture of claim 4382, wherein the condensable hydrocarbonsfurther comprise nitrogen, and wherein less than about 1% by weight,when calculated on an atomic basis, of the condensable hydrocarbons isnitrogen.
 4386. The mixture of claim 4382, wherein the condensablehydrocarbons further comprise oxygen, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is oxygen.
 4387. The mixture of claim 4382, wherein thecondensable hydrocarbons further comprise sulfur, and wherein less thanabout 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 4388. The mixture of claim 4382,wherein the condensable hydrocarbons further comprise oxygen containingcompounds, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 4389. Themixture of claim 4382, wherein the condensable hydrocarbons furthercomprise multi-ring aromatics, and wherein less than about 5% by weightof the condensable hydrocarbons comprises multi-ring aromatics with morethan two rings.
 4390. The mixture of claim 4382, wherein the condensablehydrocarbons further comprise asphaltenes, and wherein less than about0.3% by weight of the condensable hydrocarbons are asphaltenes. 4391.The mixture of claim 4382, wherein the condensable hydrocarbons comprisecycloalkanes, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 4392. The mixture ofclaim 4382, wherein greater than about 10% by volume and less than about80% by volume of the non-condensable hydrocarbons is hydrogen.
 4393. Themixture of claim 4382, further comprising ammonia, and wherein greaterthan about 0.05% by weight of the produced mixture is ammonia.
 4394. Themixture of claim 4382, further comprising ammonia, and wherein theammonia is used to produce fertilizer.
 4395. The mixture of claim 4382,wherein about 0.1% to about 5% by weight of the condensable hydrocarbonscomprises olefins.
 4396. The mixture of claim 4382, wherein about 0.1%to about 2% by weight of the condensable hydrocarbons comprises olefins.4397. The mixture of claim 4382, wherein the condensable hydrocarbonscomprises oxygenated hydrocarbons, and wherein greater than about 15% byweight of the condensable hydrocarbons comprises oxygenatedhydrocarbons.
 4398. The mixture of claim 4382, wherein the mixturecomprises hydrocarbons having greater than about 2 carbon atoms, andwherein the weight ratio of hydrocarbons having greater than about 2carbon atoms to methane is greater than about 0.3.
 4399. A condensablemixture produced from a portion of a coal formation, comprising:olefins, wherein about 0.1% by weight to about 15% by weight of thecondensable mixture comprises olefins; oxygenated hydrocarbons, whereinless than about 15% by weight of the condensable mixture comprisesoxygenated hydrocarbons; and asphaltenes, wherein less than about 0.1%by weight of the condensable mixture comprises asphaltenes.
 4400. Themixture of claim 4399, wherein the condensable mixture further compriseshydrocarbons having a carbon number of greater than approximately 25,and wherein less than about 15 weight % of the hydrocarbons in themixture have a carbon number greater than approximately
 25. 4401. Themixture of claim 4399, wherein about 0.1% by weight to about 5% byweight of the condensable mixture comprises olefins.
 4402. The mixtureof claim 4399, wherein the condensable mixture further comprisesnon-condensable hydrocarbons, wherein the non-condensable hydrocarbonscomprise ethene and ethane, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 4403. The mixture of claim 4399, wherein the condensablemixture further comprises nitrogen, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensable mixtureis nitrogen.
 4404. The mixture of claim 4399, wherein the condensablemixture further comprises oxygen, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensable mixtureis oxygen.
 4405. The mixture of claim 4399, wherein the condensablemixture further comprises sulfur, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensable mixtureis sulfur.
 4406. The mixture of claim 4399, wherein the condensablemixture further comprises oxygen containing compounds, wherein about 5%by weight to about 30% by weight of the condensable mixture compriseoxygen containing compounds, and wherein the oxygen containing compoundscomprise phenols.
 4407. The mixture of claim 4399, wherein thecondensable mixture further comprises aromatic compounds, and whereingreater than about 20% by weight of the condensable mixture are aromaticcompounds.
 4408. The mixture of claim 4399, wherein the condensablemixture further comprises multi-ring aromatics, and wherein less thanabout 5% by weight of the condensable hydrocarbons comprises multi-ringaromatics with more than two rings.
 4409. The mixture of claim 4399,wherein the condensable mixture further comprises cycloalkanes, andwherein about 5% by weight to about 30% by weight of the condensablemixture are cycloalkanes.
 4410. The mixture of claim 4399, wherein thecondensable mixture comprises non-condensable hydrocarbons, and whereinthe non-condensable hydrocarbons comprise hydrogen, and wherein thehydrogen is greater than about 10% by volume of the non-condensablehydrocarbons and wherein the hydrogen is less than about 80% by volumeof the non-condensable hydrocarbons.
 4411. The mixture of claim 4399,further comprising ammonia, and wherein greater than about 0.05% byweight of the produced mixture is ammonia.
 4412. The mixture of claim4399, further comprising ammonia, and wherein the ammonia is used toproduce fertilizer.
 4413. The mixture of claim 4399, wherein about 0.1%by weight to about 2% by weight of the condensable mixture comprisesolefins.
 4414. A condensable mixture produced from a portion of a coalformation, comprising: olefins, wherein about 0.1% by weight to about 2%by weight of the condensable mixture comprises olefins; multi-ringaromatics, wherein less than about 2% by weight of the condensablemixture comprises multi-ring aromatics with more than two rings; andoxygenated hydrocarbons, wherein greater than about 25% by weight of thecondensable mixture comprises oxygenated hydrocarbons.
 4415. The mixtureof claim 4414, further comprising hydrocarbons having a carbon number ofgreater than approximately 25, wherein less than about 5 weight % of thehydrocarbons in the mixture have a carbon number greater thanapproximately
 25. 4416. The mixture of claim 4414, wherein thecondensable mixture further comprises nitrogen, and wherein less thanabout 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 4417. The mixture of claim 4414,wherein the condensable mixture further comprises oxygen, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 4418. The mixture of claim 4414,wherein the condensable mixture further comprises sulfur, and whereinless than about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is sulfur.
 4419. The mixture of claim 4414,wherein the condensable mixture further comprises oxygen containingcompounds, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 4420. Themixture of claim 4414, wherein the condensable mixture further comprisesaromatic compounds, and wherein greater than about 20% by weight of thecondensable mixture are aromatic compounds.
 4421. The mixture of claim4414, wherein the condensable mixture further comprises condensablehydrocarbons, and wherein less than about 0.3% by weight of thecondensable hydrocarbons are asphaltenes.
 4422. The mixture of claim4414, wherein the condensable mixture further comprises cycloalkanes,and wherein about 5% by weight to about 30% by weight of the condensablehydrocarbons are cycloalkanes.
 4423. The mixture of claim 4414, furthercomprising ammonia, wherein greater than about 0.05% by weight of theproduced mixture is ammonia.
 4424. The mixture of claim 4414, furthercomprising ammonia, wherein the ammonia is used to produce fertilizer.4425. A mixture produced from a portion of a coal formation, comprising:non-condensable hydrocarbons and H₂, wherein greater than about 10% byvolume of the non-condensable hydrocarbons and H₂ comprises H₂; ammoniaand water, wherein greater than about 0.5% by weight of the mixturecomprises ammonia; and condensable hydrocarbons.
 4426. The mixture ofclaim 4425, wherein the non-condensable hydrocarbons further comprisehydrocarbons having carbon numbers of less than 5, and wherein a weightratio of the hydrocarbons having carbon numbers from 2 through 4, tomethane, in the mixture is greater than approximately
 1. 4427. Themixture of claim 4425, wherein greater than about 0.1% by weight of thecondensable hydrocarbons, and wherein less than about 15% by weight ofthe condensable hydrocarbons are olefins.
 4428. The mixture of claim4425, wherein the non-condensable hydrocarbons further comprise etheneand ethane, wherein a molar ratio of ethene to ethane in thenon-condensable hydrocarbons is greater than about 0.001, and wherein amolar ratio of ethene to ethane in the non-condensable hydrocarbons isless than about 0.15.
 4429. The mixture of claim 4425, wherein less thanabout 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is nitrogen.
 4430. The mixture of claim 4425,wherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is oxygen.
 4431. The mixture ofclaim 4425, wherein less than about 1% by weight, when calculated on anatomic basis, of the condensable hydrocarbons is sulfur.
 4432. Themixture of claim 4425, wherein about 5% by weight to about 30% by weightof the condensable hydrocarbons comprise oxygen containing compounds,and wherein the oxygen containing compounds comprise phenols.
 4433. Themixture of claim 4425, wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 4434. The mixture ofclaim 4425, wherein less than about 5% by weight of the condensablehydrocarbons comprises multi-ring aromatics with more than two rings.4435. The mixture of claim 4425, wherein less than about 0.3% by weightof the condensable hydrocarbons are asphaltenes.
 4436. The mixture ofclaim 4425, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons are cycloalkanes.
 4437. The mixture of claim4425, wherein the H₂ is less than about 80% by volume of thenon-condensable hydrocarbons and H₂.
 4438. The mixture of claim 4425,wherein the condensable hydrocarbons further comprise sulfur containingcompounds.
 4439. The mixture of claim 4425, wherein the ammonia is usedto produce fertilizer.
 4440. The mixture of claim 4425, wherein lessthan about 5% of the condensable hydrocarbons have carbon numbersgreater than
 25. 4441. The mixture of claim 4425, wherein thecondensable hydrocarbons comprise olefins, and wherein about 0.001% byweight of the condensable hydrocarbons comprise olefins, and whereinless than about 15% by weight of the condensable hydrocarbons compriseolefins.
 4442. The mixture of claim 4425, wherein the condensablehydrocarbons comprise olefins, and wherein about 0.001% by weight of thecondensable hydrocarbons comprise olefins, and wherein less than about10% by weight of the condensable hydrocarbons comprise olefins. 4443.The mixture of claim 4425, wherein the condensable hydrocarbons compriseoxygenated hydrocarbons, and wherein greater than about 1.5% by weightof the condensable hydrocarbons comprises oxygenated hydrocarbons. 4444.The mixture of claim 4425, wherein the condensable hydrocarbons furthercomprise nitrogen containing compounds.
 4445. A method of treating acoal formation in situ comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,and wherein the unit of heat sources comprises a triangular pattern.4446. The method of claim 4445, wherein three or more of the heatsources are located in the formation in a plurality of the units, andwherein the plurality of units are repeated over an area of theformation to form a repetitive pattern of units.
 4447. The method ofclaim 4445, wherein three or more of the heat sources are located in theformation in a plurality of the units, wherein the plurality of unitsare repeated over an area of the formation to form a repetitive patternof units, and wherein a ratio of heat sources in the repetitive patternof units to production wells in the repetitive pattern is less thanapproximately
 5. 4448. The method of claim 4445, wherein three or moreof the heat sources are located in the formation in a plurality of theunits, wherein the plurality of units are repeated over an area of theformation to form a repetitive pattern of units, wherein three or moreproduction wells are located within an area defined by the plurality ofunits, wherein the three or more production wells are located in theformation in a unit of production wells, and wherein the unit ofproduction wells comprises a triangular pattern.
 4449. The method ofclaim 4445, wherein three or more of the heat sources are located in theformation in a plurality of the units, wherein the plurality of unitsare repeated over an area of the formation to form a repetitive patternof units, wherein three or more injection wells are located within anarea defined by the plurality of units, wherein the three or moreinjection wells are located in the formation in a unit of injectionwells, and wherein the unit of injection wells comprises a triangularpattern.
 4450. The method of claim 4445, wherein three or more of theheat sources are located in the formation in a plurality of the units,wherein the plurality of units are repeated over an area of theformation to form a repetitive pattern of units, wherein three or moreproduction wells and three or more injection wells are located within anarea defined by the plurality of units, wherein the three or moreproduction wells are located in the formation in a unit of productionwells, wherein the unit of production wells comprises a first triangularpattern, wherein the three or more injection wells are located in theformation in a unit of injection wells, wherein the unit of injectionwells comprises a second triangular pattern, and wherein the firsttriangular pattern is substantially different than the second triangularpattern.
 4451. The method of claim 4445, wherein three or more of theheat sources are located in the formation in a plurality of the units,wherein the plurality of units are repeated over an area of theformation to form a repetitive pattern of units, wherein three or moremonitoring wells are located within an area defined by the plurality ofunits, wherein the three or more monitoring wells are located in theformation in a unit of monitoring wells, and wherein the unit ofmonitoring wells comprises a triangular pattern.
 4452. The method ofclaim 4445, wherein a production well is located in an area defined bythe unit of heat sources.
 4453. The method of claim 4445, wherein threeor more of the heat sources are located in the formation in a first unitand a second unit, wherein the first unit is adjacent to the secondunit, and wherein the first unit is inverted with respect to the secondunit.
 4454. The method of claim 4445, wherein a distance between each ofthe heat sources in the unit of heat sources varies by less than about20% .
 4455. The method of claim 4445, wherein a distance between each ofthe heat sources in the unit of heat sources is approximately equal.4456. The method of claim 4445, wherein providing heat from three ormore heat sources comprises substantially uniformly providing heat to atleast the portion of the formation.
 4457. The method of claim 4445,wherein the heated portion comprises a substantially uniform temperaturedistribution.
 4458. The method of claim 4445, wherein the heated portioncomprises a substantially uniform temperature distribution, and whereina difference between a highest temperature in the heated portion and alowest temperature in the heated portion comprises less than about 200°C.
 4459. The method of claim 4445, wherein a temperature at an outerlateral boundary of the triangular pattern and a temperature at a centerof the triangular pattern are approximately equal.
 4460. The method ofclaim 4445, wherein a temperature at an outer lateral boundary of thetriangular pattern and a temperature at a center of the triangularpattern increase substantially linearly after an initial period of time,and wherein the initial period of time comprises less than approximately3 months.
 4461. The method of claim 4445, wherein a time required toincrease an average temperature of the heated portion to a selectedtemperature with the triangular pattern of heat sources is substantiallyless than a time required to increase the average temperature of theheated portion to the selected temperature with a hexagonal pattern ofheat sources, and wherein a space between each of the heat sources inthe triangular pattern is approximately equal to a space between each ofthe heat sources in the hexagonal pattern.
 4462. The method of claim4445, wherein a time required to increase a temperature at a coldestpoint within the heated portion to a selected temperature with thetriangular pattern of heat sources is substantially less than a timerequired to increase a temperature at the coldest point within theheated portion to the selected temperature with a hexagonal pattern ofheat sources, and wherein a space between each of the heat sources inthe triangular pattern is approximately equal to a space between each ofthe heat sources in the hexagonal pattern.
 4463. The method of claim4445, wherein a time required to increase a temperature at a coldestpoint within the heated portion to a selected temperature with thetriangular pattern of heat sources is substantially less than a timerequired to increase a temperature at the coldest point within theheated portion to the selected temperature with a hexagonal pattern ofheat sources, and wherein a number of heat sources per unit area in thetriangular pattern is equal to the number of heat sources per unit arein the hexagonal pattern of heat sources.
 4464. The method of claim4445, wherein a time required to increase a temperature at a coldestpoint within the heated portion to a selected temperature with thetriangular pattern of heat sources is substantially equal to a timerequired to increase a temperature at the coldest point within theheated portion to the selected temperature with a hexagonal pattern ofheat sources, and wherein a space between each of the heat sources inthe triangular pattern is approximately 5 m greater than a space betweeneach of the heat sources in the hexagonal pattern.
 4465. The method ofclaim 4445, wherein providing heat from three or more heat sources to atleast the portion of formation comprises: heating a selected volume (V)of the coal formation from three or more of the heat sources, whereinthe formation has an average heat capacity (C_(v)), and wherein heatfrom three or more of the heat sources pyrolyzes at least somehydrocarbons within the selected volume of the formation; and whereinheating energy/day provided to the volume is equal to or less than Pwr,wherein Pwr is calculated by the equation: Pwr=h*V*C _(v)*ρ_(B) whereinPwr is the heating energy/day, h is an average heating rate of theformation, ρ_(B) is formation bulk density, and wherein the heating rateis less than about 10° C./day.
 4466. The method of claim 4445, whereinthree or more of the heat sources comprise electrical heaters.
 4467. Themethod of claim 4445, wherein three or more of the heat sources comprisesurface burners.
 4468. The method of claim 4445, wherein three or moreof the heat sources comprise flameless distributed combustors.
 4469. Themethod of claim 4445, wherein three or more of the heat sources comprisenatural distributed combustors.
 4470. The method of claim 4445, furthercomprising: allowing the heat to transfer from three or more of the heatsources to a selected section of the formation such that heat from threeor more of the heat sources pyrolyzes at least some hydrocarbons withinthe selected section of the formation; and producing a mixture of fluidsfrom the formation.
 4471. The method of claim 4470, further comprisingcontrolling a temperature within at least a majority of the selectedsection of the formation, wherein the pressure is controlled as afunction of temperature, or the temperature is controlled as a functionof pressure.
 4472. The method of claim 4470, further comprisingcontrolling the heat such that an average heating rate of the selectedsection is less than about 1.0° C. per day during pyrolysis.
 4473. Themethod of claim 4470, wherein allowing the heat to transfer from threeor more of the heat sources to the selected section comprisestransferring heat substantially by conduction.
 4474. The method of claim4470, wherein providing heat from three or more of the heat sources toat least the portion of the formation comprises heating the selectedsection such that a thermal conductivity of at least a portion of theselected section is greater than about 0.5 W/m° C.
 4475. The method ofclaim 4470, wherein the produced mixture comprises an API gravity of atleast 25°.
 4476. The method of claim 4470, wherein the produced mixturecomprises condensable hydrocarbons, and wherein about 0.1% by weight toabout 15% by weight of the condensable hydrocarbons are olefins. 4477.The method of claim 4470, wherein the produced mixture comprisesnon-condensable hydrocarbons, and wherein a molar ratio of ethene toethane in the non-condensable hydrocarbons ranges from about 0.001 toabout 0.15.
 4478. The method of claim 4470, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 1% byweight, when calculated on an atomic basis, of the condensablehydrocarbons is nitrogen.
 4479. The method of claim 4470, wherein theproduced mixture comprises condensable hydrocarbons, and wherein lessthan about 1% by weight, when calculated on an atomic basis, of thecondensable hydrocarbons is oxygen.
 4480. The method of claim 4470,wherein the produced mixture comprises condensable hydrocarbons, andwherein less than about 1% by weight, when calculated on an atomicbasis, of the condensable hydrocarbons is sulfur.
 4481. The method ofclaim 4470, wherein the produced mixture comprises condensablehydrocarbons, wherein about 5% by weight to about 30% by weight of thecondensable hydrocarbons comprise oxygen containing compounds, andwherein the oxygen containing compounds comprise phenols.
 4482. Themethod of claim 4470, wherein the produced mixture comprises condensablehydrocarbons, and wherein greater than about 20% by weight of thecondensable hydrocarbons are aromatic compounds.
 4483. The method ofclaim 4470, wherein the produced mixture comprises condensablehydrocarbons, and wherein less than about 5% by weight of thecondensable hydrocarbons comprises multi-ring aromatics with more thantwo rings.
 4484. The method of claim 4470, wherein the produced mixturecomprises condensable hydrocarbons, and wherein less than about 0.1% byweight of the condensable hydrocarbons are asphaltenes.
 4485. The methodof claim 4470, wherein the produced mixture comprises condensablehydrocarbons, and wherein about 5% by weight to about 30% by weight ofthe condensable hydrocarbons are cycloalkanes.
 4486. The method of claim4470, wherein the produced mixture comprises a non-condensablecomponent, wherein the non-condensable component comprises hydrogen,wherein the hydrogen is greater than about 10% by volume of thenon-condensable component, and wherein the hydrogen is less than about80% by volume of the non-condensable component.
 4487. The method ofclaim 4470, wherein the produced mixture comprises ammonia, and whereingreater than about 0.05% by weight of the produced mixture is ammonia.4488. The method of claim 4470, wherein the produced mixture comprisesammonia, and wherein the ammonia is used to produce fertilizer. 4489.The method of claim 4470, further comprising controlling formationconditions to produce a mixture of hydrocarbon fluids and H₂, wherein apartial pressure of H₂ within the mixture is greater than about 2.0 barabsolute.
 4490. The method of claim 4470, further comprising altering apressure within the formation to inhibit production of hydrocarbons fromthe formation having carbon numbers greater than about
 25. 4491. Themethod of claim 4470, further comprising controlling formationconditions by recirculating a portion of hydrogen from the mixture intothe formation.
 4492. The method of claim 4470, further comprising:providing hydrogen (H₂) to the heated section to hydrogenatehydrocarbons within the section; and heating a portion of the sectionwith heat from hydrogenation.
 4493. The method of claim 4470, furthercomprising: producing hydrogen from the formation; and hydrogenating aportion of the produced condensable hydrocarbons with at least a portionof the produced hydrogen.
 4494. The method of claim 4470, whereinallowing the heat to transfer from three or more of the heat sources tothe selected section of the formation comprises increasing apermeability of a majority of the selected section to greater than about100 millidarcy.
 4495. The method of claim 4470, wherein allowing theheat to transfer from three or more of the heat sources to the selectedsection of the formation comprises substantially uniformly increasing apermeability of a majority of the selected section.
 4496. The method ofclaim 4470, further comprising controlling the heat from three of moreheat sources to yield greater than about 60% by weight of condensablehydrocarbons, as measured by Fischer Assay.
 4497. The method of claim4470, wherein producing the mixture comprises producing the mixture in aproduction well, and wherein at least about 7 heat sources are disposedin the formation for each production well.
 4498. The method of claim4470, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 4499.The method of claim 4470, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 4500. A methodfor in situ production of synthesis gas from a coal formation,comprising: heating a section of the formation to a temperaturesufficient to allow synthesis gas generation, wherein a permeability ofthe section is substantially uniform and greater than a permeability ofan unheated section of the formation when the temperature sufficient toallow synthesis gas generation within the formation is achieved;providing a synthesis gas generating fluid to the section to generatesynthesis gas; and removing synthesis gas from the formation.
 4501. Themethod of claim 4500, wherein the permeability of the section is greaterthan about 100 millidarcy when the temperature sufficient to allowsynthesis gas generation within the formation is achieved.
 4502. Themethod of claim 4500, wherein the temperature sufficient to allowsynthesis gas generation ranges from approximately 400° C. toapproximately 1200° C.
 4503. The method of claim 4500, furthercomprising heating the section when providing the synthesis gasgenerating fluid to inhibit temperature decrease in the section due tosynthesis gas generation.
 4504. The method of claim 4500, whereinheating the section comprises convecting an oxidizing fluid into aportion of the section, wherein the temperature within the section isabove a temperature sufficient to support oxidation of carbon within thesection with the oxidizing fluid, and reacting the oxidizing fluid withcarbon in the section to generate heat within the section.
 4505. Themethod of claim 4504, wherein the oxidizing fluid comprises air. 4506.The method of claim 4505, wherein an amount of the oxidizing fluidconvected into the section is configured to inhibit formation of oxidesof nitrogen by maintaining a reaction temperature below a temperaturesufficient to produce oxides of nitrogen compounds.
 4507. The method ofclaim 4500, wherein heating the section comprises diffusing an oxidizingfluid to reaction zones adjacent to wellbores within the formation,oxidizing carbon within the reaction zone to generate heat, andtransferring the heat to the section.
 4508. The method of claim 4500,wherein heating the section comprises heating the section by transfer ofheat from one or more of electrical heaters.
 4509. The method of claim4500, wherein heating the section to a temperature sufficient to allowsynthesis gas generation and providing a synthesis gas generating fluidto the section comprises introducing steam into the section to heat theformation and to generate synthesis gas.
 4510. The method of claim 4500,further comprising controlling the heating of the section and provisionof the synthesis gas generating fluid to maintain a temperature withinthe section above the temperature sufficient to generate synthesis gas.4511. The method of claim 4500, further comprising: monitoring acomposition of the produced synthesis gas; and controlling heating ofthe section and provision of the synthesis gas generating fluid tomaintain the composition of the produced synthesis gas within a selectedrange.
 4512. The method of claim 4511, wherein the selected rangecomprises a ratio of H₂ to CO of about 2:1.
 4513. The method of claim4500, wherein the synthesis gas generating fluid comprises liquid water.4514. The method of claim 4500, wherein the synthesis gas generatingfluid comprises steam.
 4515. The method of claim 4500, wherein thesynthesis gas generating fluid comprises water and carbon dioxide, andwherein the carbon dioxide inhibits production of carbon dioxide fromcarbon containing material within the section.
 4516. The method of claim4515, wherein a portion of the carbon dioxide within the synthesis gasgenerating fluid comprises carbon dioxide removed from the formation.4517. The method of claim 4500, wherein the synthesis gas generatingfluid comprises carbon dioxide, and wherein a portion of the carbondioxide reacts with carbon in the formation to generate carbon monoxide.4518. The method of claim 4517, wherein a portion of the carbon dioxidewithin the synthesis gas generating fluid comprises carbon dioxideremoved from the formation.
 4519. The method of claim 4500, whereinproviding the synthesis gas generating fluid to the section comprisesraising a water table of the formation to allow water to flow into thesection.
 4520. The method of claim 4500, wherein the synthesis gas isremoved from a producer well equipped with a heating source, and whereina portion of the heating source adjacent to a synthesis gas producingzone operates at a substantially constant temperature to promoteproduction of the synthesis gas wherein the synthesis gas has a selectedcomposition.
 4521. The method of claim 4520, wherein the substantiallyconstant temperature is about 700° C., and wherein the selectedcomposition has a H₂ to CO ratio of about 2:1.
 4522. The method of claim4500, wherein the synthesis gas generating fluid comprises water andhydrocarbons having carbon numbers less than 5, and wherein at least aportion of the hydrocarbons are subjected to a reaction within thesection to increase a H₂ concentration of the generated synthesis gas.4523. The method of claim 4500, wherein the synthesis gas generatingfluid comprises water and hydrocarbons having carbon numbers greaterthan 4, and wherein at least a portion of the hydrocarbons react withinthe section to increase an energy content of the synthesis gas removedfrom the formation.
 4524. The method of claim 4500, further comprisingmaintaining a pressure within the formation during synthesis gasgeneration, and passing produced synthesis gas through a turbine togenerate electricity.
 4525. The method of claim 4500, further comprisinggenerating electricity from the synthesis gas using a fuel cell. 4526.The method of claim 4500, further comprising generating electricity fromthe synthesis gas using a fuel cell, separating carbon dioxide from afluid exiting the fuel cell, and storing a portion of the separatedcarbon dioxide within a spent section of the formation.
 4527. The methodof claim 4500, further comprising using a portion of the synthesis gasas a combustion fuel to heat the formation.
 4528. The method of claim4500, further comprising converting at least a portion of the producedsynthesis gas to condensable hydrocarbons using a Fischer-Tropschsynthesis process.
 4529. The method of claim 4500, further comprisingconverting at least a portion of the produced synthesis gas to methanol.4530. The method of claim 4500, further comprising converting at least aportion of the produced synthesis gas to gasoline.
 4531. The method ofclaim 4500, further comprising converting at least a portion of thesynthesis gas to methane using a catalytic methanation process. 4532.The method of claim 4500, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, and wherein the unit of heat sources comprises atriangular pattern.
 4533. The method of claim 4500, further comprisingproviding heat from three or more heat sources to at least a portion ofthe formation, wherein three or more of the heat sources are located inthe formation in a unit of heat sources, wherein the unit of heatsources comprises a triangular pattern, and wherein a plurality of theunits are repeated over an area of the formation to form a repetitivepattern of units.
 4534. A method of treating a coal formation in situ,comprising: providing heat from one or more heat sources to at least aportion of the formation; allowing the heat to transfer from the one ormore heat sources to substantially uniformly increase a permeability ofthe portion and to increase a temperature of the portion to atemperature sufficient to allow synthesis gas generation; providing asynthesis gas generating fluid to at least the portion of the selectedsection, wherein the synthesis gas generating fluid comprises carbondioxide; obtaining a portion of the carbon dioxide of the synthesis gasgenerating fluid from the formation; and producing synthesis gas fromthe formation.
 4535. The method of claim 4534, wherein the temperaturesufficient to allow synthesis gas generation is within a range fromabout 400° C. to about 1200° C.
 4536. The method of claim 4534, furthercomprising using a second portion of the separated carbon dioxide as aflooding agent to produce hydrocarbon bed methane from a coal formation.4537. The method of claim 4536, wherein the coal formation is a deepcoal formation over 760 m below ground surface.
 4538. The method ofclaim 4536, wherein the coal formation adsorbs some of the carbondioxide to sequester the carbon dioxide.
 4539. The method of claim 4534,further comprising using a second portion of the separated carbondioxide as a flooding agent for enhanced oil recovery.
 4540. The methodof claim 4534, wherein the synthesis gas generating fluid compriseswater and hydrocarbons having carbon numbers less than 5, and wherein atleast a portion of the hydrocarbons undergo a reaction within theselected section to increase a H₂ concentration within the producedsynthesis gas.
 4541. The method of claim 4534, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersgreater than 4, and wherein at least a portion of the hydrocarbons reactwithin the selected section to increase an energy content of theproduced synthesis gas.
 4542. The method of claim 4534, furthercomprising maintaining a pressure within the formation during synthesisgas generation, and passing produced synthesis gas through a turbine togenerate electricity.
 4543. The method of claim 4534, further comprisinggenerating electricity from the synthesis gas using a fuel cell. 4544.The method of claim 4534, further comprising generating electricity fromthe synthesis gas using a fuel cell, separating carbon dioxide from afluid exiting the fuel cell, and storing a portion of the separatedcarbon dioxide within a spent portion of the formation.
 4545. The methodof claim 4534, further comprising using a portion of the synthesis gasas a combustion fuel for heating the formation.
 4546. The method ofclaim 4534, further comprising converting at least a portion of theproduced synthesis gas to condensable hydrocarbons using aFischer-Tropsch synthesis process.
 4547. The method of claim 4534,further comprising converting at least a portion of the producedsynthesis gas to methanol.
 4548. The method of claim 4534, furthercomprising converting at least a portion of the produced synthesis gasto gasoline.
 4549. The method of claim 4534, further comprisingconverting at least a portion of the synthesis gas to methane using acatalytic methanation process.
 4550. The method of claim 4534, wherein atemperature of the one or more heat sources wellbore is maintained at atemperature of less than approximately 700° C. to produce a synthesisgas having a ratio of H₂ to carbon monoxide of greater than about 2.4551. The method of claim 4534, wherein a temperature of the one or moreheat sources wellbore is maintained at a temperature of greater thanapproximately 700° C. to produce a synthesis gas having a ratio of H₂ tocarbon monoxide of less than about
 2. 4552. The method of claim 4534,wherein a temperature of the one or more heat sources wellbore ismaintained at a temperature of approximately 700° C. to produce asynthesis gas having a ratio of H₂ to carbon monoxide of approximately2.
 4553. The method of claim 4534, wherein a heat source of the one ormore of heat sources comprises an electrical heater.
 4554. The method ofclaim 4534, wherein a heat source of the one or more heat sourcescomprises a natural distributor heater.
 4555. The method of claim 4534,wherein a heat source of the one or more heat sources comprises aflameless distributor combustor (FDC) heater, and wherein fluids areproduced from the wellbore of the FDC heater through a conduitpositioned within the wellbore.
 4556. The method of claim 4534, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, and wherein the unitof heat sources comprises a triangular pattern.
 4557. The method ofclaim 4534, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,wherein the unit of heat sources comprises a triangular pattern, andwherein a plurality of the units are repeated over an area of theformation to form a repetitive pattern of units.
 4558. A method of insitu synthesis gas production, comprising: providing heat from one ormore flameless distributed combustor heaters to at least a first portionof a coal formation; allowing the heat to transfer from the one or moreheaters to a selected section of the formation such that the heat fromthe one or more heaters substantially uniformly increases a permeabilityof the selected section, and to raise a temperature of the selectedsection to a temperature sufficient to generate synthesis gas;introducing a synthesis gas producing fluid into the selected section togenerate synthesis gas; and removing synthesis gas from the formation.4559. The method of claim 4558, wherein the one or more heaters compriseat least two heaters, and wherein superposition of heat from at leastthe two heaters substantially uniformly increases a permeability of theselected section, and raises a temperature of the selected section to atemperature sufficient to generate synthesis gas.
 4560. The method ofclaim 4558, further comprising producing the synthesis gas from theformation under pressure, and generating electricity from the producedsynthesis gas by passing the produced synthesis gas through a turbine.4561. The method of claim 4558, further comprising producingpyrolyzation products from the formation when raising the temperature ofthe selected section to the temperature sufficient to generate synthesisgas.
 4562. The method of claim 4558, further comprising separating aportion of carbon dioxide from the removed synthesis gas, and storingthe carbon dioxide within a spent portion of the formation.
 4563. Themethod of claim 4558, further comprising storing carbon dioxide within aspent portion of the formation, wherein an amount of carbon dioxidestored within the spent portion of the formation is equal to or greaterthan an amount of carbon dioxide within the removed synthesis gas. 4564.The method of claim 4558, further comprising separating a portion of H₂from the removed synthesis gas; and using a portion of the separated H₂as fuel for the one or more heaters.
 4565. The method of claim 4564,further comprising using a portion of exhaust products from one or moreheaters as a portion of the synthesis gas producing fluid
 4566. Themethod of claim 4558, further comprising using a portion of the removedsynthesis gas with a fuel cell to generate electricity.
 4567. The methodof claim 4566, wherein the fuel cell produces steam, and wherein aportion of the steam is used as a portion of the synthesis gas producingfluid.
 4568. The method of claim 4566, wherein the fuel cell producescarbon dioxide, and wherein a portion of the carbon dioxide isintroduced into the formation to react with carbon within the formationto produce carbon monoxide.
 4569. The method of claim 4566, wherein thefuel cell produces carbon dioxide, and storing an amount of carbondioxide within a spent portion of the formation equal or greater to anamount of the carbon dioxide produced by the fuel cell.
 4570. The methodof claim 4558, further comprising using a portion of the removedsynthesis gas as a feed product for formation of hydrocarbons.
 4571. Themethod of claim 4558, wherein the synthesis gas producing fluidcomprises hydrocarbons having carbon numbers less than 5, and whereinthe hydrocarbons crack within the formation to increase an amount of H₂within the generated synthesis gas.
 4572. The method of claim 4558,further comprising providing heat from three or more heat sources to atleast a portion of the formation, wherein three or more of the heatsources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 4573.The method of claim 4558, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 4574. A methodof treating a coal formation, comprising: heating a portion of theformation with one or more electrical heaters to a temperaturesufficient to pyrolyze hydrocarbons within the portion; producingpyrolyzation fluid from the formation; separating a fuel cell feedstream from the pyrolyzation fluid; and directing the fuel cell feedstream to a fuel cell to produce electricity;
 4575. The method of claim4574, wherein the fuel cell is a molten carbonate fuel cell.
 4576. Themethod of claim 4574, wherein the fuel cell is a solid oxide fuel cell.4577. The method of claim 4574, further comprising using a portion ofthe produced electricity to power the electrical heaters.
 4578. Themethod of claim 4574, wherein heating the portion of the formation isperformed at a rate sufficient to increase a permeability of the portionand to produce a substantially uniform permeability within the portion.4579. The method of claim 4574, wherein the fuel cell feed streamcomprises H₂ and hydrocarbons having a carbon number of less than 5.4580. The method of claim 4574, wherein the fuel cell feed streamcomprises H₂ and hydrocarbons having a carbon number of less than 3.4581. The method of claim 4574, further comprising hydrogenating thepyrolyzation fluid with a portion of H₂ from the pyrolyzation fluid.4582. The method of claim 4574, wherein the hydrogenation is done insitu by directing the H₂ into the formation.
 4583. The method of claim4574, wherein the hydrogenation is done in a surface unit.
 4584. Themethod of claim 4574, further comprising directing hydrocarbon fluidhaving carbon numbers less than 5 adjacent to at least one of theelectrical heaters, cracking a portion of the hydrocarbons to produceH₂, and producing a portion of the hydrogen from the formation. 4585.The method of claim 4584, further comprising directing an oxidizingfluid adjacent to at least the one of the electrical heaters, oxidizingcoke deposited on or near the at least one of the electrical heaterswith the oxidizing fluid.
 4586. The method of claim 4574, furthercomprising storing CO₂ from the fuel cell within the formation. 4587.The method of claim 4586, wherein the CO₂ is adsorbed to carbon materialwithin a spent portion of the formation.
 4588. The method of claim 4574,further comprising cooling the portion to form a spent portion offormation.
 4589. The method of claim 4588, wherein cooling the portioncomprises introducing water into the portion to produce steam, andremoving steam from the formation.
 4590. The method of claim 4589,further comprising using a portion of the removed steam to heat a secondportion of the formation.
 4591. The method of claim 4589, furthercomprising using a portion of the removed steam as a synthesis gasproducing fluid in a second portion of the formation.
 4592. The methodof claim 4574, further comprising: heating the portion to a temperaturesufficient to support generation of synthesis gas after production ofthe pyrolyzation fluids; introducing a synthesis gas producing fluidinto the portion to generate synthesis gas; and removing a portion ofthe synthesis gas from the formation.
 4593. The method of claim 4592,further comprising producing the synthesis gas from the formation underpressure, and generating electricity from the produced synthesis gas bypassing the produced synthesis gas through a turbine.
 4594. The methodof claim 4592, further comprising using a first portion of the removedsynthesis gas as fuel cell feed.
 4595. The method of claim 4592, furthercomprising producing steam from operation of the fuel cell, and usingthe steam as part of the synthesis gas producing fluid.
 4596. The methodof claim 4592, further comprising using carbon dioxide from the fuelcell as a part of the synthesis gas producing fluid.
 4597. The method ofclaim 4592, further comprising using a portion of the synthesis gas toproduce hydrocarbon product.
 4598. The method of claim 4592, furthercomprising cooling the portion to form a spent portion of formation.4599. The method of claim 4598, wherein cooling the portion comprisesintroducing water into the portion to produce steam, and removing steamfrom the formation.
 4600. The method of claim 4599, further comprisingusing a portion of the removed steam to heat a second portion of theformation.
 4601. The method of claim 4599, further comprising using aportion of the removed steam as a synthesis gas producing fluid in asecond portion of the formation.
 4602. The method of claim 4574, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, and wherein the unitof heat sources comprises a triangular pattern.
 4603. The method ofclaim 4574, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,wherein the unit of heat sources comprises a triangular pattern, andwherein a plurality of the units are repeated over an area of theformation to form a repetitive pattern of units.
 4604. A method for insitu production of synthesis gas from a coal formation, comprising:providing heat from one or more heat sources to at least a portion ofthe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation such that the heat fromthe one or more heat sources pyrolyzes at least some of the hydrocarbonswithin the selected section of the formation; producing pyrolysisproducts from the formation; heating at least a portion of the selectedsection to a temperature sufficient to generate synthesis gas; providinga synthesis gas generating fluid to at least the portion of the selectedsection to generate synthesis gas; and producing a portion of thesynthesis gas from the formation.
 4605. The method of claim 4604,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 4606. The method of claim 4604, further comprising allowingthe heat to transfer from the one or more heat sources to the selectedsection to substantially uniformly increase a permeability of theselected section.
 4607. The method of claim 4604, further comprisingcontrolling heat transfer from the one or more heat sources to produce apermeability within the selected section of greater than about 100millidarcy.
 4608. The method of claim 4604, further comprising heatingat least the portion of the selected section when providing thesynthesis gas generating fluid to inhibit temperature decrease withinthe selected section during synthesis gas generation.
 4609. The methodof claim 4604, wherein the temperature sufficient to allow synthesis gasgeneration is within a range from approximately 400° C. to approximately1200° C.
 4610. The method of claim 4604, wherein heating at least theportion of the selected section to a temperature sufficient to allowsynthesis gas generation comprises: heating zones adjacent to wellboresof one or more heat sources with heaters disposed in the wellbores,wherein the heaters are configured to raise temperatures of the zones totemperatures sufficient to support reaction of hydrocarbon materialwithin the zones with an oxidizing fluid; introducing the oxidizingfluid to the zones substantially by diffusion; allowing the oxidizingfluid to react with at least a portion of the hydrocarbon materialwithin the zones to produce heat in the zones; and transferring heatfrom the zones to the selected section.
 4611. The method of claim 4604,wherein heating at least the portion of the selected section to atemperature sufficient to allow synthesis gas generation comprises:introducing an oxidizing fluid into the formation through a wellbore;transporting the oxidizing fluid substantially be convection into theportion of the selected section, wherein the portion of the selectedsection is at a temperature sufficient to support an oxidizationreaction with the oxidizing fluid; and reacting the oxidizing fluidwithin the portion of the selected section to generate heat and raisethe temperature of the portion.
 4612. The method of claim 4604, whereinthe one or more heat sources comprise one or more electrical heatersdisposed in the formation.
 4613. The method of claim 4604, wherein oneor more heat sources comprise one or more heater wells, wherein at leastone heater well comprises a conduit disposed within the formation, andfurther comprising heating the conduit by flowing a hot fluid throughthe conduit.
 4614. The method of claim 4604, wherein heating at leastthe portion of the selected section to a temperature sufficient to allowsynthesis gas generation and providing a synthesis gas generating fluidto at least the portion of the selected section comprises introducingsteam into the portion.
 4615. The method of claim 4604, furthercomprising controlling the heating of at least the portion of selectedsection and provision of the synthesis gas generating fluid to maintaina temperature within at least the portion of the selected section abovethe temperature sufficient to generate synthesis gas.
 4616. The methodof claim 4604, further comprising: monitoring a composition of theproduced synthesis gas; and controlling heating of at least the portionof selected section and provision of the synthesis gas generating fluidto maintain the composition of the produced synthesis gas within adesired range.
 4617. The method of claim 4604, wherein the synthesis gasgenerating fluid comprises liquid water.
 4618. The method of claim 4604,wherein the synthesis gas generating fluid comprises steam.
 4619. Themethod of claim 4604, wherein the synthesis gas generating fluidcomprises water and carbon dioxide, wherein the carbon dioxide inhibitsproduction of carbon dioxide from the selected section.
 4620. The methodof claim 4619, wherein a portion of the carbon dioxide within thesynthesis gas generating fluid comprises carbon dioxide removed from theformation.
 4621. The method of claim 4604, wherein the synthesis gasgenerating fluid comprises carbon dioxide, and wherein a portion of thecarbon dioxide reacts with carbon in the formation to generate carbonmonoxide.
 4622. The method of claim 4621, wherein a portion of thecarbon dioxide within the synthesis gas generating fluid comprisescarbon dioxide removed from the formation.
 4623. The method of claim4604, wherein providing the synthesis gas generating fluid to at leastthe portion of the selected section comprises raising a water table ofthe formation to allow water to flow into the at least the portion ofthe selected section.
 4624. The method of claim 4604, wherein thesynthesis gas generating fluid comprises water and hydrocarbons havingcarbon numbers less than 5, and wherein at least a portion of thehydrocarbons are subjected to a reaction within at least the portion ofthe selected section to increase a H₂ concentration within the producedsynthesis gas.
 4625. The method of claim 4604, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersgreater than 4, and wherein at least a portion of the hydrocarbons reactwithin at least the portion of the selected section to increase anenergy content of the produced synthesis gas.
 4626. The method of claim4604, further comprising maintaining a pressure within the formationduring synthesis gas generation, and passing produced synthesis gasthrough a turbine to generate electricity.
 4627. The method of claim4604, further comprising generating electricity from the synthesis gasusing a fuel cell.
 4628. The method of claim 4604, further comprisinggenerating electricity from the synthesis gas using a fuel cell,separating carbon dioxide from a fluid exiting the fuel cell, andstoring a portion of the separated carbon dioxide within a spent sectionof the formation.
 4629. The method of claim 4604, further comprisingusing a portion of the synthesis gas as a combustion fuel for the one ormore heat sources.
 4630. The method of claim 4604, further comprisingconverting at least a portion of the produced synthesis gas tocondensable hydrocarbons using a Fischer-Tropsch synthesis process.4631. The method of claim 4604, further comprising converting at least aportion of the produced synthesis gas to methanol.
 4632. The method ofclaim 4604, further comprising converting at least a portion of theproduced synthesis gas to gasoline.
 4633. The method of claim 4604,further comprising converting at least a portion of the synthesis gas tomethane using a catalytic methanation process.
 4634. The method of claim4604, further comprising providing heat from three or more heat sourcesto at least a portion of the formation, wherein three or more of theheat sources are located in the formation in a unit of heat sources, andwherein the unit of heat sources comprises a triangular pattern. 4635.The method of claim 4604, further comprising providing heat from threeor more heat sources to at least a portion of the formation, whereinthree or more of the heat sources are located in the formation in a unitof heat sources, wherein the unit of heat sources comprises a triangularpattern, and wherein a plurality of the units are repeated over an areaof the formation to form a repetitive pattern of units.
 4636. A methodfor in situ production of synthesis gas from a coal formation,comprising: heating a first portion of the formation to pyrolyze somehydrocarbons within the first portion; allowing the heat to transferfrom one or more heat sources to a selected section of the formation,pyrolyzing hydrocarbons within the selected section; producing fluidfrom the first portion, wherein the fluid comprises an aqueous fluid anda hydrocarbon fluid; heating a second portion of the formation to atemperature sufficient to allow synthesis gas generation; introducing atleast a portion of the aqueous fluid to the second section after thesection reaches the temperature sufficient to allow synthesis gasgeneration; and producing synthesis gas from the formation.
 4637. Themethod of claim 4636, wherein the temperature sufficient to allowsynthesis gas generation ranges from approximately 400° C. toapproximately 1200° C.
 4638. The method of claim 4636, furthercomprising separating ammonia within the aqueous phase from the aqueousphase prior to introduction of at least the portion of the aqueous fluidto the second section.
 4639. The method of claim 4636, wherein apermeability of the second portion of the formation is substantiallyuniform and greater than about 100 millidarcy when the temperaturesufficient to allow synthesis gas generation is achieved.
 4640. Themethod of claim 4636, further comprising heating the second portion ofthe formation during introduction of at least the portion of the aqueousfluid to the second section to inhibit temperature decrease in thesecond section due to synthesis gas generation.
 4641. The method ofclaim 4636, wherein heating the second portion of the formationcomprises convecting an oxidizing fluid into a portion of the secondportion that is above a temperature sufficient to support oxidation ofcarbon within the portion with the oxidizing fluid, and reacting theoxidizing fluid with carbon in the portion to generate heat within theportion.
 4642. The method of claim 4636, wherein heating the secondportion of the formation comprises diffusing an oxidizing fluid toreaction zones adjacent to wellbores within the formation, oxidizingcarbon within the reaction zones to generate heat, and transferring theheat to the second portion.
 4643. The method of claim 4636, whereinheating the second portion of the formation comprises heating the secondsection by transfer of heat from one or more electrical heaters. 4644.The method of claim 4636, wherein heating the second portion of theformation comprises heating the second section with a flamelessdistributor combustor.
 4645. The method of claim 4636, wherein heatingthe second portion of the formation comprises injecting steam into atleast the portion of the formation.
 4646. The method of claim 4636,wherein at least a portion of the aqueous fluid comprises a liquidphase.
 4647. The method of claim 4636, wherein the aqueous fluidcomprises a vapor phase.
 4648. The method of claim 4636, furthercomprising adding carbon dioxide to at least the portion of aqueousfluid to inhibit production of carbon dioxide from carbon within theformation.
 4649. The method of claim 4648, wherein a portion of thecarbon dioxide comprises carbon dioxide removed from the formation.4650. The method of claim 4636, further comprising adding hydrocarbonswith carbon numbers less than 5 to at least the portion of the aqueousfluid to increase a H₂ concentration within the produced synthesis gas.4651. The method of claim 4636, further comprising adding hydrocarbonswith carbon numbers less than 5 to at least the portion of the aqueousfluid to increase a H₂ concentration within the produced synthesis gas,wherein the hydrocarbons are obtained from the produced fluid.
 4652. Themethod of claim 4636, further comprising adding hydrocarbons greaterthan 4 to at least the portion of the aqueous fluid to increase energycontent of the produced synthesis gas.
 4653. The method of claim 4636,further comprising adding hydrocarbons greater than 4 to at least theportion of the aqueous fluid to increase energy content of the producedsynthesis gas, wherein the hydrocarbons are obtained from the producedfluid.
 4654. The method of claim 4636, further comprising maintaining apressure within the formation during synthesis gas generation, andpassing produced synthesis gas through a turbine to generateelectricity.
 4655. The method of claim 4636, further comprisinggenerating electricity from the synthesis gas using a fuel cell. 4656.The method of claim 4636, further comprising generating electricity fromthe synthesis gas using a fuel cell, separating carbon dioxide from afluid exiting the fuel cell, and storing a portion of the separatedcarbon dioxide within a spent portion of the formation.
 4657. The methodof claim 4636, further comprising using a portion of the synthesis gasas a combustion fuel for the one or more heat sources.
 4658. The methodof claim 4636, further comprising converting at least a portion of theproduced synthesis gas to condensable hydrocarbons using aFischer-Tropsch synthesis process.
 4659. The method of claim 4636,further comprising converting at least a portion of the producedsynthesis gas to methanol.
 4660. The method of claim 4636, furthercomprising converting at least a portion of the produced synthesis gasto gasoline.
 4661. The method of claim 4636, further comprisingconverting at least a portion of the synthesis gas to methane using acatalytic methanation process.
 4662. The method of claim 4636, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, and wherein the unitof heat sources comprises a triangular pattern.
 4663. The method ofclaim 4636, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,wherein the unit of heat sources comprises a triangular pattern, andwherein a plurality of the units are repeated over an area of theformation to form a repetitive pattern of units.
 4664. A method for insitu production of synthesis gas from a coal formation, comprising:heating a portion of the formation with one or more heat sources tocreate increased and substantially uniform permeability within a portionof the formation and to raise a temperature within the portion to atemperature sufficient to allow synthesis gas generation; providing asynthesis gas generating fluid into the portion through at least oneinjection wellbore to generate synthesis gas from hydrocarbons and thesynthesis gas generating fluid; and producing synthesis gas from atleast one heat source wellbore in which is positioned proximate to aheat source of the one or more heat sources.
 4665. The method of claim4664, wherein the temperature sufficient to allow synthesis gasgeneration is within a range from about 400° C. to about 1200° C. 4666.The method of claim 4664, wherein creating a substantially uniformpermeability comprises heating the portion to a temperature within arange sufficient to pyrolyze hydrocarbons within the portion, raisingthe temperature within the portion at a rate of less than about 5° C.per day during pyrolyzation and removing a portion of pyrolyzed fluidfrom the formation.
 4667. The method of claim 4664, further comprisingremoving fluid from the formation through at least the one injectionwellbore prior to heating the selected section to the temperaturesufficient to allow synthesis gas generation.
 4668. The method of claim4664, wherein the injection wellbore comprises a wellbore of a heatsource in which is positioned a heat source of the one or more heatsources.
 4669. The method of claim 4664, further comprising heating theselected portion during providing the synthesis gas generating fluid toinhibit temperature decrease in at least the portion of the selectedsection due to synthesis gas generation.
 4670. The method of claim 4664,further comprising providing a portion of the heat needed to raise thetemperature sufficient to allow synthesis gas generation by convectingan oxidizing fluid to hydrocarbons within the selected section tooxidize a portion of the hydrocarbons and generate heat.
 4671. Themethod of claim 4664, further comprising controlling the heating of theselected section and provision of the synthesis gas generating fluid tomaintain a temperature within the selected section above the temperaturesufficient to generate synthesis gas.
 4672. The method of claim 4664,further comprising: monitoring a composition of the produced synthesisgas; and controlling heating of the selected section and provision ofthe synthesis gas generating fluid to maintain the composition of theproduced synthesis gas within a desired range.
 4673. The method of claim4664, wherein the synthesis gas generating fluid comprises liquid water.4674. The method of claim 4664, wherein the synthesis gas generatingfluid comprises steam.
 4675. The method of claim 4664, wherein thesynthesis gas generating fluid comprises steam to heat the selectedsection and to generate synthesis gas.
 4676. The method of claim 4664,wherein the synthesis gas generating fluid comprises water and carbondioxide.
 4677. The method of claim 4676, wherein a portion of the carbondioxide comprises carbon dioxide removed from the formation.
 4678. Themethod of claim 4664, wherein the synthesis gas generating fluidcomprises carbon dioxide, and wherein a portion of the carbon dioxidereacts with carbon in the formation to generate carbon monoxide. 4679.The method of claim 4678, wherein a portion of the carbon dioxidecomprises carbon dioxide removed from the formation.
 4680. The method ofclaim 4664, wherein providing the synthesis gas generating fluid to theselected section comprises raising a water table of the formation toallow water to enter the selected section.
 4681. The method of claim4664, wherein the synthesis gas generating fluid comprises water andhydrocarbons having carbon numbers less than 5, and wherein at least aportion of the hydrocarbons undergo a reaction within the selectedsection to increase a H₂ concentration within the produced synthesisgas.
 4682. The method of claim 4664, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersgreater than 4, and wherein at least a portion of the hydrocarbons reactwithin the selected section to increase an energy content of theproduced synthesis gas.
 4683. The method of claim 4664, furthercomprising maintaining a pressure within the formation during synthesisgas generation, and passing produced synthesis gas through a turbine togenerate electricity.
 4684. The method of claim 4664, further comprisinggenerating electricity from the synthesis gas using a fuel cell. 4685.The method of claim 4664, further comprising generating electricity fromthe synthesis gas using a fuel cell, separating carbon dioxide from afluid exiting the fuel cell, and storing a portion of the separatedcarbon dioxide within a spent portion of the formation.
 4686. The methodof claim 4664, further comprising using a portion of the synthesis gasas a combustion fuel for heating the formation.
 4687. The method ofclaim 4664, further comprising converting at least a portion of theproduced synthesis gas to condensable hydrocarbons using aFischer-Tropsch synthesis process.
 4688. The method of claim 4664,further comprising converting at least a portion of the producedsynthesis gas to methanol.
 4689. The method of claim 4664, furthercomprising converting at least a portion of the produced synthesis gasto gasoline.
 4690. The method of claim 4664, further comprisingconverting at least a portion of the synthesis gas to methane using acatalytic methanation process.
 4691. The method of claim 4664, wherein atemperature of at least the one heat source wellbore is maintained at atemperature of less than approximately 700° C. to produce a synthesisgas having a ratio of H₂ to carbon monoxide of greater than about 2.4692. The method of claim 4664, wherein a temperature of at least theone heat source wellbore is maintained at a temperature of greater thanapproximately 700° C. to produce a synthesis gas having a ratio of H₂ tocarbon monoxide of less than about
 2. 4693. The method of claim 4664,wherein a temperature of at least the one heat source wellbore ismaintained at a temperature of approximately 700° C. to produce asynthesis gas having a ratio of H₂ to carbon monoxide of approximately2.
 4694. The method of claim 4664, wherein a heat source of the one ormore heat sources comprises an electrical heater.
 4695. The method ofclaim 4664, wherein a heat source of the one or more heat sourcescomprises a natural distributor heater.
 4696. The method of claim 4664,wherein a heat source of the one or more heat sources comprises aflameless distributor combustor (FDC) heater, and wherein fluids areproduced from the wellbore of the FDC heater through a conduitpositioned within the wellbore.
 4697. The method of claim 4664, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, and wherein the unitof heat sources comprises a triangular pattern.
 4698. The method ofclaim 4664, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,wherein the unit of heat sources comprises a triangular pattern, andwherein a plurality of the units are repeated over an area of theformation to form a repetitive pattern of units.
 4699. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation such that the heat from the one or more heatsources pyrolyzes at least a portion of hydrocarbon material within theselected section of the formation; producing pyrolysis products from theformation; heating a first portion of a formation with one or more heatsources to a temperature sufficient to allow generation of synthesisgas; providing a first synthesis gas generating fluid to the firstportion to generate a first synthesis gas; removing a portion of thefirst synthesis gas from the formation; heating a second portion of aformation with one more heat sources to a temperature sufficient toallow generation of synthesis gas having a H₂ to CO ratio greater than aH₂ to CO ratio of the first synthesis gas; providing a second synthesisgas generating component to the second portion to generate a secondsynthesis gas; removing a portion of the second synthesis gas from theformation; and blending a portion of the first synthesis gas with aportion of the second synthesis gas to produce a blended synthesis gashaving a selected H₂ to CO ratio.
 4700. The method of claim 4699,wherein the one or more heat sources comprise at least two heat sources,and wherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 4701. The method of claim 4699, wherein the first synthesisgas generating fluid and second synthesis gas generating fluid are thesame component.
 4702. The method of claim 4699, further comprisingcontrolling the temperature in the first portion to control acomposition of the first synthesis gas.
 4703. The method of claim 4699,further comprising controlling the temperature in the second portion tocontrol a composition of the second synthesis gas.
 4704. The method ofclaim 4699, wherein the selected ratio is controlled to be approximately2:1 H₂ to CO.
 4705. The method of claim 4699, wherein the selected ratiois controlled to range from approximately 1.8:1 to approximately 2.2:1H₂to CO.
 4706. The method of claim 4699, wherein the selected ratio iscontrolled to be approximately 3:1 H₂ to CO.
 4707. The method of claim4699, wherein the selected ratio is controlled to range fromapproximately 2.8:1 to approximately 3.2:1 H₂to CO.
 4708. The method ofclaim 4699, further comprising providing at least a portion of theproduced blended synthesis gas to a condensable hydrocarbon synthesisprocess to produce condensable hydrocarbons.
 4709. The method of claim4708, wherein the condensable hydrocarbon synthesis process comprises aFischer-Tropsch process.
 4710. The method of claim 4709, furthercomprising cracking at least a portion of the condensable hydrocarbonsto form middle distillates.
 4711. The method of claim 4699, furthercomprising providing at least a portion of the produced blendedsynthesis gas to a catalytic methanation process to produce methane.4712. The method of claim 4699, further comprising providing at least aportion of the produced blended synthesis gas to a methanol-synthesisprocess to produce methanol.
 4713. The method of claim 4699, furthercomprising providing at least a portion of the produced blendedsynthesis gas to a gasoline-synthesis process to produce gasoline. 4714.The method of claim 4699, wherein removing a portion of the secondsynthesis gas comprises withdrawing second synthesis gas through aproduction well, wherein a temperature of the production well adjacentto a second syntheses gas production zone is maintained at asubstantially constant temperature configured to produce secondsynthesis gas having the H₂ to CO ratio greater the first synthesis gas.4715. The method of claim 4699, wherein the first synthesis gasproducing fluid comprises CO₂ and wherein the temperature of the firstportion is at a temperature that will result in conversion of CO₂ andcarbon from the first portion to CO to generate a CO rich firstsynthesis gas.
 4716. The method of claim 4699, wherein the secondsynthesis gas producing fluid comprises water and hydrocarbons havingcarbon numbers less than 5, and wherein at least a portion of thehydrocarbons react within the formation to increase a H₂ concentrationwithin the produced second synthesis gas.
 4717. The method of claim4699, wherein blending a portion of the first synthesis gas with aportion of the second synthesis gas comprises producing an intermediatemixture having a H₂ to CO mixture of less than the selected ratio, andsubjecting the intermediate mixture to a shift reaction to reduce anamount of CO and increase an amount of H₂ to produce the selected ratioof H₂ to CO.
 4718. The method of claim 4699, further comprising removingan excess of first synthesis gas from the first portion to have anexcess of CO, subjecting the first synthesis gas to a shift reaction toreduce an amount of CO and increase an amount of H₂ before blending thefirst synthesis gas with the second synthesis gas.
 4719. The method ofclaim 4699, further comprising removing the first synthesis gas from theformation under pressure, and passing removed first synthesis gasthrough a turbine to generate electricity.
 4720. The method of claim4699, further comprising removing the second synthesis gas from theformation under pressure, and passing removed second synthesis gasthrough a turbine to generate electricity.
 4721. The method of claim4699, further comprising generating electricity from the blendedsynthesis gas using a fuel cell.
 4722. The method of claim 4699, furthercomprising generating electricity from the blended synthesis gas using afuel cell, separating carbon dioxide from a fluid exiting the fuel cell,and storing a portion of the separated carbon dioxide within a spentportion of the formation.
 4723. The method of claim 4699, furthercomprising using at least a portion of the blended synthesis gas as acombustion fuel for heating the formation.
 4724. The method of claim4699, further comprising allowing the heat to transfer from the one ormore heat sources to the selected section to substantially uniformlyincrease a permeability of the selected section.
 4725. The method ofclaim 4699, further comprising controlling heat transfer from the one ormore heat sources to produce a permeability within the selected sectionof greater than about 100 millidarcy.
 4726. The method of claim 4699,further comprising heating at least the portion of the selected sectionwhen providing the synthesis gas generating fluid to inhibit temperaturedecrease within the selected section during synthesis gas generation.4727. The method of claim 4699, wherein the temperature sufficient toallow synthesis gas generation is within a range from approximately 400°C. to approximately 1200° C.
 4728. The method of claim 4699, whereinheating the first a portion of the selected section to a temperaturesufficient to allow synthesis gas generation comprises: heating zonesadjacent to wellbores of one or more heat sources with heaters disposedin the wellbores, wherein the heaters are configured to raisetemperatures of the zones to temperatures sufficient to support reactionof hydrocarbon material within the zones with an oxidizing fluid;introducing the oxidizing fluid to the zones substantially by diffusion;allowing the oxidizing fluid to react with at least a portion of thehydrocarbon material within the zones to produce heat in the zones; andtransferring heat from the zones to the selected section.
 4729. Themethod of claim 4699, wherein heating the second portion of the selectedsection to a temperature sufficient to allow synthesis gas generationcomprises: heating zones adjacent to wellbores of one or more heatsources with heaters disposed in the wellbores, wherein the heaters areconfigured to raise temperatures of the zones to temperatures sufficientto support reaction of hydrocarbon material within the zones with anoxidizing fluid; introducing the oxidizing fluid to the zonessubstantially by diffusion; allowing the oxidizing fluid to react withat least a portion of the hydrocarbon material within the zones toproduce heat in the zones; and transferring heat from the zones to theselected section.
 4730. The method of claim 4699, wherein heating thefirst portion of the selected section to a temperature sufficient toallow synthesis gas generation comprises: introducing an oxidizing fluidinto the formation through a wellbore; transporting the oxidizing fluidsubstantially by convection into the first portion of the selectedsection, wherein the first portion of the selected section is at atemperature sufficient to support an oxidization reaction with theoxidizing fluid; and reacting the oxidizing fluid within the firstportion of the selected section to generate heat and raise thetemperature of the first portion.
 4731. The method of claim 4699,wherein heating the second portion of the selected section to atemperature sufficient to allow synthesis gas generation comprises:introducing an oxidizing fluid into the formation through a wellbore;transporting the oxidizing fluid substantially by convection into thesecond portion of the selected section, wherein the second portion ofthe selected section is at a temperature sufficient to support anoxidization reaction with the oxidizing fluid; and reacting theoxidizing fluid within the second portion of the selected section togenerate heat and raise the temperature of the second portion.
 4732. Themethod of claim 4699, wherein the one or more heat sources comprise oneor more electrical heaters disposed in the formation.
 4733. The methodof claim 4699, wherein the one or more heat sources comprises one ormore natural distributor combustors.
 4734. The method of claim 4699,wherein the one or more heat sources comprise one or more heater wells,wherein at least one heater well comprises a conduit disposed within theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 4735. The method of claim 4699, whereinheating the first portion of the selected section to a temperaturesufficient to allow synthesis gas generation and providing a firstsynthesis gas generating fluid to the first portion of the selectedsection comprises introducing steam into the first portion.
 4736. Themethod of claim 4699, wherein heating the second portion of the selectedsection to a temperature sufficient to allow synthesis gas generationand providing a second synthesis gas generating fluid to the secondportion of the selected section comprises introducing steam into thesecond portion.
 4737. The method of claim 4699, further comprisingcontrolling the heating of the first portion of selected section andprovision of the first synthesis gas generating fluid to maintain atemperature within the first portion of the selected section above thetemperature sufficient to generate synthesis gas.
 4738. The method ofclaim 4699, further comprising controlling the heating of the secondportion of selected section and provision of the second synthesis gasgenerating fluid to maintain a temperature within the second portion ofthe selected section above the temperature sufficient to generatesynthesis gas.
 4739. The method of claim 4699, wherein the firstsynthesis gas generating fluid comprises liquid water.
 4740. The methodof claim 4699, wherein the second synthesis gas generating fluidcomprises liquid water.
 4741. The method of claim 4699, wherein thefirst synthesis gas generating fluid comprises steam.
 4742. The methodof claim 4699, wherein the second synthesis gas generating fluidcomprises steam.
 4743. The method of claim 4699, wherein the firstsynthesis gas generating fluid comprises water and carbon dioxide,wherein the carbon dioxide inhibits production of carbon dioxide fromthe selected section.
 4744. The method of claim 4743, wherein a portionof the carbon dioxide within the first synthesis gas generating fluidcomprises carbon dioxide removed from the formation.
 4745. The method ofclaim 4699, wherein the second synthesis gas generating fluid compriseswater and carbon dioxide, wherein the carbon dioxide inhibits productionof carbon dioxide from the selected section.
 4746. The method of claim4745, wherein a portion of the carbon dioxide within the secondsynthesis gas generating fluid comprises carbon dioxide removed from theformation.
 4747. The method of claim 4699, wherein the first synthesisgas generating fluid comprises carbon dioxide, and wherein a portion ofthe carbon dioxide reacts with carbon in the formation to generatecarbon monoxide.
 4748. The method of claim 4747, wherein a portion ofthe carbon dioxide within the first synthesis gas generating fluidcomprises carbon dioxide removed from the formation.
 4749. The method ofclaim 4699, wherein the second synthesis gas generating fluid comprisescarbon dioxide, and wherein a portion of the carbon dioxide reacts withcarbon in the formation to generate carbon monoxide.
 4750. The method ofclaim 4749, wherein a portion of the carbon dioxide within the secondsynthesis gas generating fluid comprises carbon dioxide removed from theformation.
 4751. The method of claim 4699, wherein providing the firstsynthesis gas generating fluid to the first portion of the selectedsection comprises raising a water table of the formation to allow waterto flow into the first portion of the selected section.
 4752. The methodof claim 4699, wherein providing the second synthesis gas generatingfluid to the second portion of the selected section comprises raising awater table of the formation to allow water to flow into the secondportion of the selected section.
 4753. The method of claim 4699, whereinthe first synthesis gas generating fluid comprises water andhydrocarbons having carbon numbers less than 5, and wherein at least aportion of the hydrocarbons are subjected to a reaction within the firstportion of the selected section to increase a H₂ concentration withinthe produced first synthesis gas.
 4754. The method of claim 4699,wherein the second synthesis gas generating fluid comprises water andhydrocarbons having carbon numbers less than 5, and wherein at least aportion of the hydrocarbons are subjected to a reaction within thesecond portion of the selected section to increase a H₂ concentrationwithin the produced second synthesis gas.
 4755. The method of claim4699, wherein the first synthesis gas generating fluid comprises waterand hydrocarbons having carbon numbers greater than 4, and wherein atleast a portion of the hydrocarbons react within the first portion ofthe selected section to increase an energy content of the produced firstsynthesis gas.
 4756. The method of claim 4699, wherein the secondsynthesis gas generating fluid comprises water and hydrocarbons havingcarbon numbers greater than 4, and wherein at least a portion of thehydrocarbons react within at least the second portion of the selectedsection to increase an energy content of the second produced synthesisgas.
 4757. The method of claim 4699, further comprising maintaining apressure within the formation during synthesis gas generation, andpassing produced blended synthesis gas through a turbine to generateelectricity.
 4758. The method of claim 4699, further comprisinggenerating electricity from the blended synthesis gas using a fuel cell.4759. The method of claim 4699, further comprising generatingelectricity from the blended synthesis gas using a fuel cell, separatingcarbon dioxide from a fluid exiting the fuel cell, and storing a portionof the separated carbon dioxide within a spent section of the formation.4760. The method of claim 4699, further comprising using a portion ofthe blended synthesis gas as a combustion fuel for the one or more heatsources.
 4761. The method of claim 4699, further comprising using aportion of the first synthesis gas as a combustion fuel for the one ormore heat sources.
 4762. The method of claim 4699, further comprisingusing a portion of the second synthesis gas as a combustion fuel for theone or more heat sources.
 4763. The method of claim 4699, furthercomprising using a portion of the blended synthesis gas as a combustionfuel for the one or more heat sources.
 4764. A method of treating a coalformation in situ, comprising: providing heat from one or more heatsources to at least a portion of the formation; allowing the heat totransfer from the one or more heat sources to a selected section of theformation such that the heat from the one or more heat sources pyrolyzesat least some of the hydrocarbons within the selected section of theformation; producing pyrolysis products from the formation; heating atleast a portion of the selected section to a temperature sufficient togenerate synthesis gas; controlling a temperature of at least a portionof the selected section to generate synthesis gas having a selected H₂to CO ratio; providing a synthesis gas generating fluid to at least theportion of the selected section to generate synthesis gas; and producinga portion of the synthesis gas from the formation.
 4765. The method ofclaim 4764, wherein the one or more heat sources comprise at least twoheat sources, and wherein superposition of heat from at least the twoheat sources pyrolyzes at least some hydrocarbons within the selectedsection of the formation.
 4766. The method of claim 4764, wherein theselected ratio is controlled to be approximately 2:1 H₂ to CO.
 4767. Themethod of claim 4764, wherein the selected ratio is controlled to rangefrom approximately 1.8:1 to approximately 2.2:1 H₂ to CO.
 4768. Themethod of claim 4764, wherein the selected ratio is controlled to beapproximately 3:1 H₂ to CO.
 4769. The method of claim 4764, wherein theselected ratio is controlled to range from approximately 2.8:1 toapproximately 3.2:1 H₂ to CO.
 4770. The method of claim 4764, furthercomprising providing at least a portion of the produced synthesis gas toa condensable hydrocarbon synthesis process to produce condensablehydrocarbons.
 4771. The method of claim 4770, wherein the condensablehydrocarbon synthesis process comprises a Fischer-Tropsch process. 4772.The method of claim 4771, further comprising cracking at least a portionof the condensable hydrocarbons to form middle distillates.
 4773. Themethod of claim 4764, further comprising providing at least a portion ofthe produced synthesis gas to a catalytic methanation process to producemethane.
 4774. The method of claim 4764, further comprising providing atleast a portion of the produced synthesis gas to a methanol-synthesisprocess to produce methanol.
 4775. The method of claim 4764, furthercomprising providing at least a portion of the produced synthesis gas toa gasoline-synthesis process to produce gasoline.
 4776. The method ofclaim 4764, further comprising allowing the heat to transfer from theone or more heat sources to the selected section to substantiallyuniformly increase a permeability of the selected section.
 4777. Themethod of claim 4764, further comprising controlling heat transfer fromthe one or more heat sources to produce a permeability within theselected section of greater than about 100 millidarcy.
 4778. The methodof claim 4764, further comprising heating at least the portion of theselected section when providing the synthesis gas generating fluid toinhibit temperature decrease within the selected section duringsynthesis gas generation.
 4779. The method of claim 4764, wherein thetemperature sufficient to allow synthesis gas generation is within arange from approximately 400° C. to approximately 1200° C.
 4780. Themethod of claim 4764, wherein heating at least the portion of theselected section to a temperature sufficient to allow synthesis gasgeneration comprises: heating zones adjacent to wellbores of one or moreheat sources with heaters disposed in the wellbores, wherein the heatersare configured to raise temperatures of the zones to temperaturessufficient to support reaction of hydrocarbon material within the zoneswith an oxidizing fluid; introducing the oxidizing fluid to the zonessubstantially by diffusion; allowing the oxidizing fluid to react withat least a portion of the hydrocarbon material within the zones toproduce heat in the zones; and transferring heat from the zones to theselected section.
 4781. The method of claim 4764, wherein heating atleast the portion of the selected section to a temperature sufficient toallow synthesis gas generation comprises: introducing an oxidizing fluidinto the formation through a wellbore; transporting the oxidizing fluidsubstantially by convection into the portion of the selected section,wherein the portion of the selected section is at a temperaturesufficient to support an oxidization reaction with the oxidizing fluid;and reacting the oxidizing fluid within the portion of the selectedsection to generate heat and raise the temperature of the portion. 4782.The method of claim 4764, wherein the one or more heat sources compriseone or more electrical heaters disposed in the formation.
 4783. Themethod of claim 4764, wherein the one or more heat sources comprises oneor more natural distributor combustors.
 4784. The method of claim 4764,wherein the one or more heat sources comprise one or more heater wells,wherein at least one heater well comprises a conduit disposed within theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 4785. The method of claim 4764, whereinheating at least the portion of the selected section to a temperaturesufficient to allow synthesis gas generation and providing a synthesisgas generating fluid to at least the portion of the selected sectioncomprises introducing steam into the portion.
 4786. The method of claim4764, further comprising controlling the heating of at least the portionof selected section and provision of the synthesis gas generating fluidto maintain a temperature within at least the portion of the selectedsection above the temperature sufficient to generate synthesis gas.4787. The method of claim 4764, wherein the synthesis gas generatingfluid comprises liquid water.
 4788. The method of claim 4764, whereinthe synthesis gas generating fluid comprises steam.
 4789. The method ofclaim 4764, wherein the synthesis gas generating fluid comprises waterand carbon dioxide, wherein the carbon dioxide inhibits production ofcarbon dioxide from the selected section.
 4790. The method of claim4789, wherein a portion of the carbon dioxide within the synthesis gasgenerating fluid comprises carbon dioxide removed from the formation.4791. The method of claim 4764, wherein the synthesis gas generatingfluid comprises carbon dioxide, and wherein a portion of the carbondioxide reacts with carbon in the formation to generate carbon monoxide.4792. The method of claim 4791, wherein a portion of the carbon dioxidewithin the synthesis gas generating fluid comprises carbon dioxideremoved from the formation.
 4793. The method of claim 4764, whereinproviding the synthesis gas generating fluid to at least the portion ofthe selected section comprises raising a water table of the formation toallow water to flow into the at least the portion of the selectedsection.
 4794. The method of claim 4764, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersless than 5, and wherein at least a portion of the hydrocarbons aresubjected to a reaction within at least the portion of the selectedsection to increase a H₂ concentration within the produced synthesisgas.
 4795. The method of claim 4764, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersgreater than 4, and wherein at least a portion of the hydrocarbons reactwithin at least the portion of the selected section to increase anenergy content of the produced synthesis gas.
 4796. The method of claim4764, further comprising maintaining a pressure within the formationduring synthesis gas generation, and passing produced synthesis gasthrough a turbine to generate electricity.
 4797. The method of claim4764, further comprising generating electricity from the synthesis gasusing a fuel cell.
 4798. The method of claim 4764, further comprisinggenerating electricity from the synthesis gas using a fuel cell,separating carbon dioxide from a fluid exiting the fuel cell, andstoring a portion of the separated carbon dioxide within a spent sectionof the formation.
 4799. The method of claim 4764, further comprisingusing a portion of the synthesis gas as a combustion fuel for the one ormore heat sources.
 4800. A method of treating a coal formation in situ,comprising: providing heat from one or more heat sources to at least aportion of the formation; allowing the heat to transfer from the one ormore heat sources to a selected section of the formation such that theheat from the one or more heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation; producingpyrolysis products from the formation; heating at least a portion of theselected section to a temperature sufficient to generate synthesis gas;controlling a temperature in or proximate to a synthesis gas productionwell to generate synthesis gas having a selected H₂ to CO ratio;providing a synthesis gas generating fluid to at least the portion ofthe selected section to generate synthesis gas; and producing synthesisgas from the formation.
 4801. The method of claim 4800, wherein the oneor more heat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.4802. The method of claim 4800, wherein the selected ratio is controlledto be approximately 2:1 H₂ to CO.
 4803. The method of claim 4800,wherein the selected ratio is controlled to range from approximately1.8:1 to approximately 2.2:1 H₂to CO.
 4804. The method of claim 4800,wherein the selected ratio is controlled to be approximately 3:1 H₂ toCO.
 4805. The method of claim 4800, wherein the selected ratio iscontrolled to range from approximately 2.8:1 to approximately 3.2:1 H₂to CO.
 4806. The method of claim 4800, further comprising providing atleast a portion of the produced synthesis gas to a condensablehydrocarbon synthesis process to produce condensable hydrocarbons. 4807.The method of claim 4806, wherein the condensable hydrocarbon synthesisprocess comprises a Fischer-Tropsch process.
 4808. The method of claim4807, further comprising cracking at least a portion of the condensablehydrocarbons to form middle distillates.
 4809. The method of claim 4800,further comprising providing at least a portion of the producedsynthesis gas to a catalytic methanation process to produce methane.4810. The method of claim 4800, further comprising providing at least aportion of the produced synthesis gas to a methanol-synthesis process toproduce methanol.
 4811. The method of claim 4800, further comprisingproviding at least a portion of the produced synthesis gas to agasoline-synthesis process to produce gasoline.
 4812. The method ofclaim 4800, further comprising allowing the heat to transfer from theone or more heat sources to the selected section to substantiallyuniformly increase a permeability of the selected section.
 4813. Themethod of claim 4800, further comprising controlling heat transfer fromthe one or more heat sources to produce a permeability within theselected section of greater than about 100 millidarcy.
 4814. The methodof claim 4800, further comprising heating at least the portion of theselected section when providing the synthesis gas generating fluid toinhibit temperature decrease within the selected section duringsynthesis gas generation.
 4815. The method of claim 4800, wherein thetemperature sufficient to allow synthesis gas generation is within arange from approximately 400° C. to approximately 1200° C.
 4816. Themethod of claim 4800, wherein heating at least the portion of theselected section to a temperature sufficient to allow synthesis gasgeneration comprises: heating zones adjacent to wellbores of one or moreheat sources with heaters disposed in the wellbores, wherein the heatersare configured to raise temperatures of the zones to temperaturessufficient to support reaction of hydrocarbon material within the zoneswith an oxidizing fluid; introducing the oxidizing fluid to the zonessubstantially by diffusion; allowing the oxidizing fluid to react withat least a portion of the hydrocarbon material within the zones toproduce heat in the zones; and transferring heat from the zones to theselected section.
 4817. The method of claim 4800, wherein heating atleast the portion of the selected section to a temperature sufficient toallow synthesis gas generation comprises: introducing an oxidizing fluidinto the formation through a wellbore; transporting the oxidizing fluidsubstantially by convection into the portion of the selected section,wherein the portion of the selected section is at a temperaturesufficient to support an oxidization reaction with the oxidizing fluid;and reacting the oxidizing fluid within the portion of the selectedsection to generate heat and raise the temperature of the portion. 4818.The method of claim 4800, wherein the one or more heat sources compriseone or more electrical heaters disposed in the formation.
 4819. Themethod of claim 4800, wherein the one or more heat sources comprises oneor more natural distributor combustors.
 4820. The method of claim 4800,wherein the one or more heat sources comprise one or more heater wells,wherein at least one heater well comprises a conduit disposed within theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 4821. The method of claim 4800, whereinheating at least the portion of the selected section to a temperaturesufficient to allow synthesis gas generation and providing a synthesisgas generating fluid to at least the portion of the selected sectioncomprises introducing steam into the portion.
 4822. The method of claim4800, further comprising controlling the heating of at least the portionof selected section and provision of the synthesis gas generating fluidto maintain a temperature within at least the portion of the selectedsection above the temperature sufficient to generate synthesis gas.4823. The method of claim 4800, wherein the synthesis gas generatingfluid comprises liquid water.
 4824. The method of claim 4800, whereinthe synthesis gas generating fluid comprises steam.
 4825. The method ofclaim 4800, wherein the synthesis gas generating fluid comprises waterand carbon dioxide.
 4826. The method of claim 4825, wherein a portion ofthe carbon dioxide within the synthesis gas generating fluid comprisescarbon dioxide removed from the formation.
 4827. The method of claim4800, wherein the synthesis gas generating fluid comprises carbondioxide, and wherein a portion of the carbon dioxide reacts with carbonin the formation to generate carbon monoxide.
 4828. The method of claim4827, wherein a portion of the carbon dioxide within the synthesis gasgenerating fluid comprises carbon dioxide removed from the formation.4829. The method of claim 4800, wherein providing the synthesis gasgenerating fluid to at least the portion of the selected sectioncomprises raising a water table of the formation to allow water to flowinto the at least the portion of the selected section.
 4830. The methodof claim 4800, wherein the synthesis gas generating fluid compriseswater and hydrocarbons having carbon numbers less than 5, and wherein atleast a portion of the hydrocarbons are subjected to a reaction withinat least the portion of the selected section to increase a H₂concentration within the produced synthesis gas.
 4831. The method ofclaim 4800, wherein the synthesis gas generating fluid comprises waterand hydrocarbons having carbon numbers greater than 4, and wherein atleast a portion of the hydrocarbons react within at least the portion ofthe selected section to increase an energy content of the producedsynthesis gas.
 4832. The method of claim 4800, further comprisingmaintaining a pressure within the formation during synthesis gasgeneration, and passing produced synthesis gas through a turbine togenerate electricity.
 4833. The method of claim 4800, further comprisinggenerating electricity from the synthesis gas using a fuel cell. 4834.The method of claim 4800, further comprising generating electricity fromthe synthesis gas using a fuel cell, separating carbon dioxide from afluid exiting the fuel cell, and storing a portion of the separatedcarbon dioxide within a spent section of the formation.
 4835. The methodof claim 4800, further comprising using a portion of the synthesis gasas a combustion fuel for the one or more heat sources.
 4836. A method oftreating a coal formation in situ, comprising: providing heat from oneor more heat sources to at least a portion of the formation; allowingthe heat to transfer from the one or more heat sources to a selectedsection of the formation such that the heat from the one or more heatsources pyrolyzes at least some of the hydrocarbons within the selectedsection of the formation; producing pyrolysis products from theformation; heating at least a portion of the selected section to atemperature sufficient to generate synthesis gas; controlling atemperature of at least a portion of the selected section to generatesynthesis gas having a H₂ to CO ratio different than a selected H₂ to COratio; providing a synthesis gas generating fluid to at least theportion of the selected section to generate synthesis gas; and producingsynthesis gas from the formation; providing at least a portion of theproduced synthesis gas to a shift process wherein an amount of carbonmonoxide is converted to carbon dioxide; separating at least a portionof the carbon dioxide to obtain a gas having a selected H₂ to CO ratio.4837. The method of claim 4836, wherein the one or more heat sourcescomprise at least two heat sources, and wherein superposition of heatfrom at least the two heat sources pyrolyzes at least some hydrocarbonswithin the selected section of the formation.
 4838. The method of claim4836, wherein the selected ratio is controlled to be approximately 2:1H₂ to CO.
 4839. The method of claim 4836, wherein the selected ratio iscontrolled to range from approximately 1.8:1 to 2.2:1 H₂to CO.
 4840. Themethod of claim 4836, wherein the selected ratio is controlled to beapproximately 3:1 H₂ to CO.
 4841. The method of claim 4836, wherein theselected ratio is controlled to range from approximately 2.8:1 to 3.2:1H₂to CO.
 4842. The method of claim 4836, further comprising providing atleast a portion of the produced synthesis gas to a condensablehydrocarbon synthesis process to produce condensable hydrocarbons. 4843.The method of claim 4842, wherein the condensable hydrocarbon synthesisprocess comprises a Fischer-Tropsch process.
 4844. The method of claim4843, further comprising cracking at least a portion of the condensablehydrocarbons to form middle distillates.
 4845. The method of claim 4836,further comprising providing at least a portion of the producedsynthesis gas to a catalytic methanation process to produce methane.4846. The method of claim 4836, further comprising providing at least aportion of the produced synthesis gas to a methanol-synthesis process toproduce methanol.
 4847. The method of claim 4836, further comprisingproviding at least a portion of the produced synthesis gas to agasoline-synthesis process to produce gasoline.
 4848. The method ofclaim 4836, further comprising allowing the heat to transfer from theone or more heat sources to the selected section to substantiallyuniformly increase a permeability of the selected section.
 4849. Themethod of claim 4836, further comprising controlling heat transfer fromthe one or more heat sources to produce a permeability within theselected section of greater than about 100 millidarcy.
 4850. The methodof claim 4836, further comprising heating at least the portion of theselected section when providing the synthesis gas generating fluid toinhibit temperature decrease within the selected section duringsynthesis gas generation.
 4851. The method of claim 4836, wherein thetemperature sufficient to allow synthesis gas generation is within arange from approximately 400° C. to approximately 1200° C.
 4852. Themethod of claim 4836, wherein heating at least the portion of theselected section to a temperature sufficient to allow synthesis gasgeneration comprises: heating zones adjacent to wellbores of one or moreheat sources with heaters disposed in the wellbores, wherein the heatersare configured to raise temperatures of the zones to temperaturessufficient to support reaction of hydrocarbon material within the zoneswith an oxidizing fluid; introducing the oxidizing fluid to the zonessubstantially by diffusion; allowing the oxidizing fluid to react withat least a portion of the hydrocarbon material within the zones toproduce heat in the zones; and transferring heat from the zones to theselected section.
 4853. The method of claim 4836, wherein heating atleast the portion of the selected section to a temperature sufficient toallow synthesis gas generation comprises: introducing an oxidizing fluidinto the formation through a wellbore; transporting the oxidizing fluidsubstantially by convection into the portion of the selected section,wherein the portion of the selected section is at a temperaturesufficient to support an oxidization reaction with the oxidizing fluid;and reacting the oxidizing fluid within the portion of the selectedsection to generate heat and raise the temperature of the portion. 4854.The method of claim 4836, wherein the one or more heat sources compriseone or more electrical heaters disposed in the formation.
 4855. Themethod of claim 4836, wherein the one or more heat sources comprises oneor more natural distributor combustors.
 4856. The method of claim 4836,wherein the one or more heat sources comprise one or more heater wells,wherein at least one heater well comprises a conduit disposed within theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 4857. The method of claim 4836, whereinheating at least the portion of the selected section to a temperaturesufficient to allow synthesis gas generation and providing a synthesisgas generating fluid to at least the portion of the selected sectioncomprises introducing steam into the portion.
 4858. The method of claim4836, further comprising controlling the heating of at least the portionof selected section and provision of the synthesis gas generating fluidto maintain a temperature within at least the portion of the selectedsection above the temperature sufficient to generate synthesis gas.4859. The method of claim 4836, wherein the synthesis gas generatingfluid comprises liquid water.
 4860. The method of claim 4836, whereinthe synthesis gas generating fluid comprises steam.
 4861. The method ofclaim 4836, wherein the synthesis gas generating fluid comprises waterand carbon dioxide, wherein the carbon dioxide inhibits production ofcarbon dioxide from the selected section.
 4862. The method of claim4861, wherein a portion of the carbon dioxide within the synthesis gasgenerating fluid comprises carbon dioxide removed from the formation.4863. The method of claim 4836, wherein the synthesis gas generatingfluid comprises carbon dioxide, and wherein a portion of the carbondioxide reacts with carbon in the formation to generate carbon monoxide.4864. The method of claim 4863, wherein a portion of the carbon dioxidewithin the synthesis gas generating fluid comprises carbon dioxideremoved from the formation.
 4865. The method of claim 4836, whereinproviding the synthesis gas generating fluid to at least the portion ofthe selected section comprises raising a water table of the formation toallow water to flow into the at least the portion of the selectedsection.
 4866. The method of claim 4836, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersless than 5, and wherein at least a portion of the hydrocarbons aresubjected to a reaction within at least the portion of the selectedsection to increase a H₂ concentration within the produced synthesisgas.
 4867. The method of claim 4836, wherein the synthesis gasgenerating fluid comprises water and hydrocarbons having carbon numbersgreater than 4, and wherein at least a portion of the hydrocarbons reactwithin at least the portion of the selected section to increase anenergy content of the produced synthesis gas.
 4868. The method of claim4836, further comprising maintaining a pressure within the formationduring synthesis gas generation, and passing produced synthesis gasthrough a turbine to generate electricity.
 4869. The method of claim4836, further comprising generating electricity from the synthesis gasusing a fuel cell.
 4870. The method of claim 4836, further comprisinggenerating electricity from the synthesis gas using a fuel cell,separating carbon dioxide from a fluid exiting the fuel cell, andstoring a portion of the separated carbon dioxide within a spent sectionof the formation.
 4871. The method of claim 4836, further comprisingusing a portion of the synthesis gas as a combustion fuel for the one ormore heat sources.
 4872. A method of forming a spent portion offormation within a coal formation, comprising: heating a first portionof the formation to pyrolyze hydrocarbons within the first portion andto establish a substantially uniform permeability within the firstportion; and cooling the first portion.
 4873. The method of claim 4872,wherein heating the first portion comprises transferring heat to thefirst portion from one or more electrical heaters.
 4874. The method ofclaim 4872, wherein heating the first portion comprises transferringheat to the first portion from one or more natural distributorcombustors.
 4875. The method of claim 4872, wherein heating the firstportion comprises transferring heat to the first portion from one ormore flameless distributor combustors.
 4876. The method of claim 4872,wherein heating the first portion comprises transferring heat to thefirst portion from heat transfer fluid flowing within one or morewellbores within the formation.
 4877. The method of claim 4876, whereinthe heat transfer fluid comprises steam.
 4878. The method of claim 4876,wherein the heat transfer fluid comprises combustion products from aburner.
 4879. The method of claim 4872, wherein heating the firstportion comprises transferring heat to the first portion from at leasttwo heater wells positioned within the formation, wherein the at leasttwo heater wells are placed in a substantially regular pattern, whereinthe substantially regular pattern comprises repetition of a base heaterunit, and wherein the base heater unit is formed of a number of heaterwells.
 4880. The method of claim 4879, wherein a spacing between a pairof adjacent heater wells is within a range from about 6 m to about 15 m.4881. The method of claim 4879, further comprising removing fluid fromthe formation through one or more production wells.
 4882. The method ofclaim 4881, wherein the one or more production wells are located in apattern, and wherein the one or more production wells are positionedsubstantially at centers of base heater units.
 4883. The method of claim4879, wherein the heater unit comprises three heater wells positionedsubstantially at apexes of an equilateral triangle.
 4884. The method ofclaim 4879, wherein the heater unit comprises four heater wellspositioned substantially at apexes of a rectangle.
 4885. The method ofclaim 4879, wherein the heater unit comprises five heater wellspositioned substantially at apexes of a regular pentagon.
 4886. Themethod of claim 4879, wherein the heater unit comprises six heater wellspositioned substantially at apexes of a regular hexagon.
 4887. Themethod of claim 4872, further comprising introducing water to the firstportion to cool the formation.
 4888. The method of claim 4872, furthercomprising removing steam from the formation.
 4889. The method of claim4888, further comprising using a portion of the removed steam to heat asecond portion of the formation.
 4890. The method of claim 4872, furthercomprising removing pyrolyzation products from the formation.
 4891. Themethod of claim 4872, further comprising generating synthesis gas withinthe portion by introducing a synthesis gas generating fluid into theportion, and removing synthesis gas from the formation.
 4892. The methodof claim 4872, further comprising heating a second section of theformation to pyrolyze hydrocarbons within the second portion, removingpyrolyzation fluid from the second portion, and storing a portion of theremoved pyrolyzation fluid within the first portion.
 4893. The method ofclaim 4892, wherein the portion of the removed pyrolyzation fluid isstored within the first portion when surface facilities that process theremoved pyrolyzation fluid are not able to process the portion of theremoved pyrolyzation fluid.
 4894. The method of claim 4892, furthercomprising heating the first portion to facilitate removal of the storedpyrolyzation fluid from the first portion.
 4895. The method of claim4872, further comprising generating synthesis gas within a secondportion of the formation, removing synthesis gas from the secondportion, and storing a portion of the removed synthesis gas within thefirst portion.
 4896. The method of claim 4895, wherein the portion ofthe removed synthesis gas from the second portion are stored within thefirst portion when surface facilities that process the removed synthesisgas are not able to process the portion of the removed synthesis gas.4897. The method of claim 4895, further comprising heating the firstportion to facilitate removal of the stored synthesis gas from the firstportion.
 4898. The method of claim 4872, further comprising removing atleast a portion of carbon containing material in the first portion.4899. The method of claim 4898, further comprising using at least aportion of the carbon containing material removed from the formation ina metallurgical application.
 4900. The method of claim 4899, wherein themetallurgical application comprises steel manufacturing.
 4901. A methodof sequestering carbon dioxide within a coal formation, comprising:heating a portion of the formation to increase permeability and form asubstantially uniform permeability within the portion; allowing theportion to cool; and storing carbon dioxide within the portion. 4902.The method of claim 4901, wherein the permeability of the portion isincreased to over 100 millidarcy.
 4903. The method of claim 4901,further comprising raising a water level within the portion to inhibitmigration of the carbon dioxide from the portion.
 4904. The method ofclaim 4901, further comprising heating the portion to release carbondioxide, and removing carbon dioxide from the portion.
 4905. The methodof claim 4901, further comprising pyrolyzing hydrocarbons within theportion during heating of the portion, and removing pyrolyzation productfrom the formation.
 4906. The method of claim 4901, further comprisingproducing synthesis gas from the portion during the heating of theportion, and removing synthesis gas from the formation.
 4907. The methodof claim 4901, wherein heating the portion comprises: heatinghydrocarbon material adjacent to one or more wellbores to a temperaturesufficient to support oxidation of the hydrocarbon material with anoxidizing fluid; introducing the oxidizing fluid to hydrocarbon materialadjacent to the one or more wellbores to oxidize hydrocarbons andproduce heat; and conveying produced heat to the portion.
 4908. Themethod of claim 4907, wherein heating hydrocarbon material adjacent tothe one or more wells comprises electrically heating the hydrocarbonmaterial.
 4909. The method of claim 4907, wherein the temperaturesufficient to support oxidation is in a range between approximately 200°C. to approximately 1200° C.
 4910. The method of claim 4901, whereinheating the portion comprises circulating heat transfer fluid throughone or more heating wells within the formation.
 4911. The method ofclaim 4910, wherein the heat transfer fluid comprises combustionproducts from a burner.
 4912. The method of claim 4910, wherein the heattransfer fluid comprises steam.
 4913. The method of claim 4901, furthercomprising removing fluid from the formation during heating of theformation, and combusting a portion of the removed fluid to generateheat to heat the formation.
 4914. The method of claim 4901, furthercomprising using at least a portion of the carbon dioxide forhydrocarbon bed demethanation prior to storing the carbon dioxide withinthe portion.
 4915. The method of claim 4901, further comprising using aportion of the carbon dioxide for enhanced oil recovery prior to storingthe carbon dioxide within the portion.
 4916. The method of claim 4901,wherein at least a portion of the carbon dioxide comprises carbondioxide generated in a fuel cell.
 4917. The method of claim 4901,wherein at least a portion of the carbon dioxide comprises carbondioxide formed as a combustion product.
 4918. The method of claim 4901,further comprising allowing the portion to cool by introducing water tothe portion; and removing the water from the formation as steam. 4919.The method of claim 4918, further comprising using the steam as a heattransfer fluid to heat a second portion of the formation.
 4920. Themethod of claim 4901, wherein storing carbon dioxide in the portioncomprises adsorbing carbon dioxide to carbon containing material withinthe formation.
 4921. The method of claim 4901, wherein storing carbondioxide comprises passing a first fluid stream comprising the carbondioxide and other fluid through the portion; adsorbing carbon dioxideonto carbon containing material within the formation; and removing asecond fluid stream from the formation, wherein a concentration of theother fluid in the second fluid stream is greater than concentration ofother fluid in the first stream due to the absence of the adsorbedcarbon dioxide in the second stream.
 4922. The method of claim 4901,wherein an amount of carbon dioxide stored within the portion is equalto or greater than an amount of carbon dioxide generated within theportion and removed from the formation during heating of the portion.4923. The method of claim 4901, further comprising providing heat fromthree or more heat sources to at least a portion of the formation,wherein three or more of the heat sources are located in the formationin a unit of heat sources, and wherein the unit of heat sourcescomprises a triangular pattern.
 4924. The method of claim 4901, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, wherein the unit ofheat sources comprises a triangular pattern, and wherein a plurality ofthe units are repeated over an area of the formation to form arepetitive pattern of units.
 4925. A method of in situ sequestration ofcarbon dioxide within a coal formation in situ, comprising: providingheat from one or more heat sources to at least a first portion of theformation; allowing the heat to transfer from one or more sources to aselected section of the formation such that the heat from the one ormore heat sources pyrolyzes at least some hydrocarbons within theselected section of the formation; producing pyrolyzation fluids,wherein the pyrolyzation fluids comprise carbon dioxide; and storing anamount of carbon dioxide in the formation, wherein the amount of storedcarbon dioxide is equal to or greater than an amount of carbon dioxidewithin the pyrolyzation fluids.
 4926. The method of claim 4925, whereinthe one or more heat sources comprise at least two heat sources, andwherein superposition of heat from at least the two heat sourcespyrolyzes at least some hydrocarbons within the selected section of theformation.
 4927. The method of claim 4925, wherein the carbon dioxide isstored within a spent portion of the formation.
 4928. The method ofclaim 4925, wherein a portion of the carbon dioxide stored within theformation is carbon dioxide separated from the pyrolyzation fluids.4929. The method of claim 4925, further comprising separating a portionof carbon dioxide from the pyrolyzation fluids, and using the carbondioxide as a flooding agent in enhanced oil recovery.
 4930. The methodof claim 4925, further comprising separating a portion of carbon dioxidefrom the pyrolyzation fluids, and using the carbon dioxide as asynthesis gas generating fluid for the generation of synthesis gas froma section of the formation that is heated to a temperature sufficient togenerate synthesis gas upon introduction of the synthesis gas generatingfluid.
 4931. The method of claim 4925, further comprising separating aportion of carbon dioxide from the pyrolyzation fluids, and using thecarbon dioxide to displace hydrocarbon bed methane.
 4932. The method ofclaim 4931, wherein the hydrocarbon bed is a deep hydrocarbon bedlocated over 760 m below ground surface.
 4933. The method of claim 4931,further comprising adsorbing a portion of the carbon dioxide within thehydrocarbon bed.
 4934. The method of claim 4925, further comprisingusing at least a portion of the pyrolyzation fluids as a feed stream fora fuel cell.
 4935. The method of claim 4934, wherein the fuel cellgenerates carbon dioxide, and further comprising storing an amount ofcarbon dioxide equal to or greater than an amount of carbon dioxidegenerated by the fuel cell within the formation.
 4936. The method ofclaim 4925, wherein a spent portion of the formation comprises carboncontaining material within a section of the formation that has beenheated and from which hydrocarbons have been produced, and wherein thespent portion of the formation is at a temperature at which carbondioxide adsorbs onto the carbon containing material.
 4937. The method ofclaim 4925, further comprising raising a water level within the spentportion to inhibit migration of the carbon dioxide from the portion.4938. The method of claim 4925, wherein producing fluids from theformation comprises removing pyrolyzation products from the formation.4939. The method of claim 4925, wherein producing fluids from theformation comprises heating the selected section to a temperaturesufficient to generate synthesis gas; introducing a synthesis gasgenerating fluid into the selected section; and removing synthesis gasfrom the formation.
 4940. The method of claim 4939, wherein thetemperature sufficient to generate synthesis gas ranges from about 400°C. to about 1200° C.
 4941. The method of claim 4939, wherein heating theselected section comprises introducing an oxidizing fluid into theselected section, reacting the oxidizing fluid within the selectedsection to heat the selected section.
 4942. The method of claim 4939,wherein heating the selected section comprises: heating hydrocarbonmaterial adjacent to one or more wellbores to a temperature sufficientto support oxidation of the hydrocarbon material with an oxidant;introducing the oxidant to hydrocarbon material adjacent to the one ormore wellbores to oxidize hydrocarbons and produce heat; and conveyingproduced heat to the portion.
 4943. The method of claim 4925, whereinthe spent portion of the formation comprises a substantially uniformpermeability created by heating the spent formation and removing fluidduring formation of the spent portion.
 4944. The method of claim 4925,wherein the one or more heat sources comprise electrical heaters. 4945.The method of claim 4925, wherein the one or more heat sources compriseflameless distributor combustors.
 4946. The method of claim 4945,wherein a portion of fuel for the one or more flameless distributorcombustors is obtained from the formation.
 4947. The method of claim4925, wherein the one or more heat sources comprise heater wells in theformation through which heat transfer fluid is circulated.
 4948. Themethod of claim 4947, wherein the heat transfer fluid comprisescombustion products.
 4949. The method of claim 4947, wherein the heattransfer fluid comprises steam.
 4950. The method of claim 4925, whereincondensable hydrocarbons are produced under pressure, and furthercomprising generating electricity by passing a portion of the producedfluids through a turbine.
 4951. The method of claim 4925, furthercomprising providing heat from three or more heat sources to at least aportion of the formation, wherein three or more of the heat sources arelocated in the formation in a unit of heat sources, and wherein the unitof heat sources comprises a triangular pattern.
 4952. The method ofclaim 4925, further comprising providing heat from three or more heatsources to at least a portion of the formation, wherein three or more ofthe heat sources are located in the formation in a unit of heat sources,wherein the unit of heat sources comprises a triangular pattern, andwherein a plurality of the units are repeated over an area of theformation to form a repetitive pattern of units.
 4953. A method for insitu production of energy from a coal formation, comprising: providingheat from one or more heat sources to at least a portion of theformation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation such that the heat fromthe one or more heat sources pyrolyzes at least a portion ofhydrocarbons within the selected section of the formation; producingpyrolysis products from the formation; providing at least a portion ofthe pyrolysis products to a reformer to generate synthesis gas;producing the synthesis gas from the reformer; providing at least aportion of the produced synthesis gas to a fuel cell to produceelectricity, wherein the fuel cell produces a carbon dioxide containingexit stream; and storing at least a portion of the carbon dioxide in thecarbon dioxide containing exit stream in a subsurface formation. 4954.The method of claim 4953, wherein the one or more heat sources compriseat least two heat sources, and wherein superposition of heat from atleast the two heat sources pyrolyzes at least some hydrocarbons withinthe selected section of the formation.
 4955. The method of claim 4953,wherein at least a portion of the pyrolysis products are used as fuel inthe reformer.
 4956. The method of claim 4953, wherein the synthesis gascomprises carbon dioxide and H₂.
 4957. The method of claim 4953, whereinthe subsurface formation is a spent portion of the formation.
 4958. Themethod of claim 4953, wherein the subsurface formation is an oilreservoir.
 4959. The method of claim 4958, wherein at least a portion ofthe carbon dioxide is used as a drive fluid for enhanced oil recovery inthe oil reservoir.
 4960. The method of claim 4953, wherein thesubsurface formation is a second coal formation.
 4961. The method ofclaim 4960, wherein the second coal formation is located greater thanabout 760 m below ground surface.
 4962. The method of claim 4960,wherein at least a portion of the carbon dioxide is used to producemethane from the second coal formation.
 4963. The method of claim 4962,further comprising sequestering at least a portion of the carbon dioxidewithin the second coal formation.
 4964. The method of claim 4953,wherein the reformer produces a reformer carbon dioxide containing exitstream.
 4965. The method of claim 4963, further comprising storing atleast a portion of the carbon dioxide in the reformer carbon dioxidecontaining exit stream in the subsurface formation.
 4966. The method ofclaim 4965, wherein the subsurface formation is a spent portion of theformation.
 4967. The method of claim 4965, wherein the subsurfaceformation is an oil reservoir.
 4968. The method of claim 4967, whereinat least a portion of the carbon dioxide in the reformer carbon dioxidecontaining exit stream is used as a drive fluid for enhanced oilrecovery in the oil reservoir.
 4969. The method of claim 4965, whereinthe subsurface formation is a second coal formation.
 4970. The method ofclaim 4868, wherein at least a portion of the carbon dioxide in thereformer carbon dioxide containing exit stream is used to producemethane from the second coal formation.
 4971. The method of claim 4970,further comprising sequestering at least a portion of the carbon dioxidein the reformer carbon dioxide containing exit stream within the secondcoal formation.
 4972. The method of claim 4969, wherein the second coalformation is located greater than about 760 m below ground surface.4973. The method of claim 4953, wherein the fuel cell is a moltencarbonate fuel cell.
 4974. The method of claim 4953, wherein the fuelcell is a solid oxide fuel cell.
 4975. The method of claim 4953, furthercomprising using a portion of the produced electricity to powerelectrical heaters within the formation.
 4976. The method of claim 4953,further comprising using a portion of the produced pyrolysis products asa feed stream for the fuel cell.
 4977. The method of claim 4953, whereinthe one or more heat sources comprise one or more electrical heatersdisposed in the formation.
 4978. The method of claim 4953, wherein theone or more heat sources comprise one or more flameless distributorcombustors disposed in the formation.
 4979. The method of claim 4978,wherein a portion of fuel for the flameless distributor combustors isobtained from the formation.
 4980. The method of claim 4953, wherein theone or more heat sources comprise one or more heater wells, wherein atleast one heater well comprises a conduit disposed within the formation,and further comprising heating the conduit by flowing a hot fluidthrough the conduit.
 4981. The method of claim 4953, further comprisingusing a portion of the synthesis gas as a combustion fuel for the one ormore heat sources.
 4982. A method for producing ammonia using a coalformation, comprising: separating air to produce an O₂ rich stream and aN₂ rich stream; heating a selected section of the formation to atemperature sufficient to support reaction of hydrocarbon material inthe formation to form synthesis gas; providing synthesis gas generatingfluid and at least a portion of the O₂ rich stream to the selectedsection; allowing the synthesis gas generating fluid and O₂ in the O₂rich stream to react with at least a portion of the hydrocarbon materialin the formation to generate synthesis gas; producing synthesis gas fromthe formation, wherein the synthesis gas comprises H₂ and CO; providingat least a portion of the H₂ in the synthesis gas to an ammoniasynthesis process; providing N₂ to the ammonia synthesis process; andusing the ammonia synthesis process to generate ammonia.
 4983. Themethod of claim 4982, wherein the ratio of the H₂ to N₂ provided to theammonia synthesis process is approximately 3:1.
 4984. The method ofclaim 4982, wherein the ratio of the H₂ to N₂ provided to the ammoniasynthesis process ranges from approximately 2.8:1 to approximately3.2:1.
 4985. The method of claim 4982, wherein the temperaturesufficient to support reaction of hydrocarbon material in the formationto form synthesis gas ranges from approximately 400° C. to approximately1200° C.
 4986. The method of claim 4982, further comprising separatingat least a portion of carbon dioxide in the synthesis gas from at leasta portion of the synthesis gas.
 4987. The method of claim 4986, whereinthe carbon dioxide is separated from the synthesis gas by an amineseparator.
 4988. The method of claim 4987, further comprising providingat least a portion of the carbon dioxide to a urea synthesis process toproduce urea.
 4989. The method of claim 4982, wherein at least a portionof the N₂ stream is used to condense hydrocarbons with 4 or more carbonatoms from a pyrolyzation fluid.
 4990. The method of claim 4982, whereinat least a portion of the N₂ rich stream is provided to the ammoniasynthesis process.
 4991. The method of claim 4982, wherein the air isseparated by cryogenic distillation.
 4992. The method of claim 4982,wherein the air is separated by membrane separation.
 4993. The method ofclaim 4982, wherein fluids produced during pyrolysis of a coal formationcomprise ammonia and, further comprising adding at least a portion ofsuch ammonia to the ammonia generated from the ammonia synthesisprocess.
 4994. The method of claim 4982, wherein fluids produced duringpyrolysis of a coal formation are hydrotreated and at least some ammoniais produced during hydrotreating, and, further comprising adding atleast a portion of such ammonia to the ammonia generated from theammonia synthesis process.
 4995. The method of claim 4982, furthercomprising providing at least a portion of the ammonia to a ureasynthesis process to produce urea.
 4996. The method of claim 4982,further comprising providing at least a portion of the ammonia to a ureasynthesis process to produce urea and, further comprising providingcarbon dioxide from the formation to the urea synthesis process. 4997.The method of claim 4982, further comprising providing at least aportion of the ammonia to a urea synthesis process to produce urea and,further comprising shifting at least a portion of the carbon monoxide tocarbon dioxide in a shift process, and further comprising providing atleast a portion of the carbon dioxide from the shift process to the ureasynthesis process.
 4998. The method of claim 4982, wherein heating theselected section of the formation to a temperature to support reactionof hydrocarbon material in the formation to form synthesis gascomprises: heating zones adjacent to wellbores of one or more heatsources with heaters disposed in the wellbores, wherein the heaters areconfigured to raise temperatures of the zones to temperatures sufficientto support reaction of hydrocarbon material within the zones with O₂ inthe O₂ rich stream; introducing the O₂ to the zones substantially bydiffusion; allowing O₂ in the O₂ rich stream to react with at least aportion of the hydrocarbon material within the zones to produce heat inthe zones; and transferring heat from the zones to the selected section.4999. The method of claim 4998, wherein temperatures sufficient tosupport reaction of hydrocarbon within the zones with O₂ range fromapproximately 200° C. to approximately 1200° C.
 5000. The method ofclaim 4998, wherein the one or more heat sources comprises one or moreelectrical heaters disposed in the formation.
 5001. The method of claim4998, wherein the one or more heat sources comprises one or more naturaldistributor combustors.
 5002. The method of claim 4998, wherein the oneor more heat sources comprise one or more heater wells, wherein at leastone heater well comprises a conduit disposed within the formation, andfurther comprising heating the conduit by flowing a hot fluid throughthe conduit.
 5003. The method of claim 4998, further comprising using aportion of the synthesis gas as a combustion fuel for the one or moreheat sources.
 5004. The method of claim 4982, wherein heating theselected section of the formation to a temperature to support reactionof hydrocarbon material in the formation to form synthesis gascomprises: introducing the O₂ rich stream into the formation through awellbore; transporting O₂ in the O₂ rich stream substantially byconvection into the portion of the selected section, wherein the portionof the selected section is at a temperature sufficient to support anoxidization reaction with O₂ in the O₂ rich stream; and reacting the O₂within the portion of the selected section to generate heat and raisethe temperature of the portion.
 5005. The method of claim 5005, whereinthe temperature sufficient to support an oxidization reaction with O₂ranges from approximately 200° C. to approximately 1200° C.
 5006. Themethod of claim 5005, wherein the one or more heat sources comprises oneor more electrical heaters disposed in the formation.
 5007. The methodof claim 5005, wherein the one or more heat sources comprises one ormore natural distributor combustors.
 5008. The method of claim 5005,wherein the one or more heat sources comprise one or more heater wells,wherein at least one heater well comprises a conduit disposed within theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 5009. The method of claim 5005, furthercomprising using a portion of the synthesis gas as a combustion fuel forthe one or more heat sources.
 5010. The method of claim 4982, furthercomprising controlling the heating of at least the portion of theselected section and provision of the synthesis gas generating fluid tomaintain a temperature within at least the portion of the selectedsection above the temperature sufficient to generate synthesis gas.5011. The method of claim 4982, wherein the synthesis gas generatingfluid comprises liquid water.
 5012. The method of claim 4982, whereinthe synthesis gas generating fluid comprises steam.
 5013. The method ofclaim 4982, wherein the synthesis gas generating fluid comprises waterand carbon dioxide wherein the carbon dioxide inhibits production ofcarbon dioxide from the selected section.
 5014. The method of claim5013, wherein a portion of the carbon dioxide within the synthesis gasgenerating fluid comprises carbon dioxide removed from the formation.5015. The method of claim 4982, wherein the synthesis gas generatingfluid comprises carbon dioxide, and wherein a portion of the carbondioxide reacts with carbon in the formation to generate carbon monoxide.5016. The method of claim 5015, wherein a portion of the carbon dioxidewithin the synthesis gas generating fluid comprises carbon dioxideremoved from the formation.
 5017. The method of claim 4982, whereinproviding the synthesis gas generating fluid to at least the portion ofthe selected section comprises raising a water table of the formation toallow water to flow into the at least the portion of the selectedsection.
 5018. A method for producing ammonia using a coal formation,comprising: generating a first ammonia feed stream from a first portionof the formation; generating a second ammonia feed stream from a secondportion of the formation, wherein the second ammonia feed stream has aH₂ to N₂ ratio greater than a H₂ to N₂ ratio of the first ammonia feedstream; blending at least a portion of the first ammonia feed streamwith at least a portion of the second ammonia feed stream to produce ablended ammonia feed stream having a selected H₂ to N₂ ratio; providingthe blended ammonia feed stream to an ammonia synthesis process; andusing the ammonia synthesis process to generate ammonia.
 5019. Themethod of claim 5018, wherein the selected ratio is approximately 3:1.5020. The method of claim 5018, wherein the selected ratio ranges fromapproximately 2.8:1 to approximately 3.2:1.
 5021. The method of claim5018, further comprising separating at least a portion of carbon dioxidein the first ammonia feed stream from at least a portion of the firstammonia feed stream.
 5022. The method of claim 5021, wherein the carbondioxide is separated from the first ammonia feed stream by an amineseparator.
 5023. The method of claim 5022, further comprising providingat least a portion of the carbon dioxide to a urea synthesis process.5024. The method of claim 5018, further comprising separating at least aportion of carbon dioxide in the blended ammonia feed stream from atleast a portion of the blended ammonia feed stream.
 5025. The method ofclaim 5024, wherein the carbon dioxide is separated from the blendedammonia feed stream by an amine separator.
 5026. The method of claim5025, further comprising providing at least a portion of the carbondioxide to a urea synthesis process
 5027. The method of claim 5018,further comprising separating at least a portion of carbon dioxide inthe second ammonia feed stream from at least a portion of the secondammonia feed stream.
 5028. The method of claim 5027, wherein the carbondioxide is separated from the second ammonia feed stream by an amineseparator.
 5029. The method of claim 5028, further comprising providingat least a portion of the carbon dioxide to a urea synthesis process.5030. The method of claim 5018, wherein fluids produced during pyrolysisof a coal formation comprise ammonia and, further comprising adding atleast a portion of such ammonia to the ammonia generated from theammonia synthesis process.
 5031. The method of claim 5018, whereinfluids produced during pyrolysis of a coal formation are hydrotreatedand at least some ammonia is produced during hydrotreating, and furthercomprising adding at least a portion of such ammonia to the ammoniagenerated from the ammonia synthesis process.
 5032. The method of claim5018, further comprising providing at least a portion of the ammonia toa urea synthesis process to produce urea.
 5033. The method of claim5018, further comprising providing at least a portion of the ammonia toa urea synthesis process to produce urea and, further comprisingproviding carbon dioxide from the formation to the urea synthesisprocess.
 5034. The method of claim 5018, further comprising providing atleast a portion of the ammonia to a urea synthesis process to produceurea and further comprising shifting at least a portion of carbonmonoxide in the blended ammonia feed stream to carbon dioxide in a shiftprocess, and further comprising providing at least a portion of thecarbon dioxide from the shift process to the urea synthesis process.5035. A method for producing ammonia using a coal formation, comprising:heating a selected section of the formation to a temperature sufficientto support reaction of hydrocarbon material in the formation to formsynthesis gas; providing a synthesis gas generating fluid and an O₂ richstream to the selected section, wherein the amount of N₂ in the O₂ richstream is sufficient to generate synthesis gas having a selected ratioof H₂ to N₂; allowing the synthesis gas generating fluid and O₂ in theO₂ rich stream to react with at least a portion of the hydrocarbonmaterial in the formation to generate synthesis gas having a selectedratio of H₂ to N₂; producing the synthesis gas from the formation;providing at least a portion of the H₂ and N₂ in the synthesis gas to anammonia synthesis process; using the ammonia synthesis process togenerate ammonia.
 5036. The method of claim 5035, further comprisingcontrolling a temperature of at least a portion of the selected sectionto generate synthesis gas having the selected H₂ to N₂ ratio.
 5037. Themethod of claim 5035, wherein the selected ratio is approximately 3:1.5038. The method of claim 5035, wherein the selected ratio ranges fromapproximately 2.8:1 to 3.2:1.
 5039. The method of claim 5035, whereinthe temperature sufficient to support reaction of hydrocarbon materialin the formation to form synthesis gas ranges from approximately 400° C.to approximately 1200° C.
 5040. The method of claim 5035, wherein the O₂stream and N₂ stream are obtained by cryogenic separation of air. 5041.The method of claim 5035, wherein the O₂ stream and N₂ stream areobtained by membrane separation of air.
 5042. The method of claim 5035,further comprising separating at least a portion of carbon dioxide inthe synthesis gas from at least a portion of the synthesis gas. 5043.The method of claim 5042, wherein the carbon dioxide is separated fromthe synthesis gas by an amine separator.
 5044. The method of claim 5043,further comprising providing at least a portion of the carbon dioxide toa urea synthesis process.
 5045. The method of claim 5035, wherein fluidsproduced during pyrolysis of a coal formation comprise ammonia and,further comprising adding at least a portion of such ammonia to theammonia generated from the ammonia synthesis process.
 5046. The methodof claim 5035, wherein fluids produced during pyrolysis of a coalformation are hydrotreated and at least some ammonia is produced duringhydrotreating, and further comprising adding at least a portion of suchammonia to the ammonia generated from the ammonia synthesis process.5047. The method of claim 5035, further comprising providing at least aportion of the ammonia to a urea synthesis process to produce urea.5048. The method of claim 5035, further comprising providing at least aportion of the ammonia to a urea synthesis process to produce urea and,further comprising providing carbon dioxide from the formation to theurea synthesis process.
 5049. The method of claim 5035, furthercomprising providing at least a portion of the ammonia to a ureasynthesis process to produce urea and further comprising shifting atleast a portion of carbon monoxide in the synthesis gas to carbondioxide in a shift process, and further comprising providing at least aportion of the carbon dioxide from the shift process to the ureasynthesis process.
 5050. The method of claim 5035, wherein heating aselected section of the formation to a temperature to support reactionof hydrocarbon material in the formation to form synthesis gascomprises: heating zones adjacent to wellbores of one or more heatsources with heaters disposed in the wellbores, wherein the heaters areconfigured to raise temperatures of the zones to temperatures sufficientto support reaction of hydrocarbon material within the zones with O₂ inthe O₂ rich stream; introducing the O₂ to the zones substantially bydiffusion; allowing O₂ in the O₂ rich stream to react with at least aportion of the hydrocarbon material within the zones to produce heat inthe zones; and transferring heat from the zones to the selected section.5051. The method of claim 5050, wherein temperatures sufficient tosupport reaction of hydrocarbon material within the zones with O₂ rangefrom approximately 200° C. to approximately 1200° C.
 5052. The method ofclaim 5050, wherein the one or more heat sources comprises one or moreelectrical heaters disposed in the formation.
 5053. The method of claim5050, wherein the one or more heat sources comprises one or more naturaldistributor combustors.
 5054. The method of claim 5050, wherein the oneor more heat sources comprise one or more heater wells, wherein at leastone heater well comprises a conduit disposed within the formation, andfurther comprising heating the conduit by flowing a hot fluid throughthe conduit.
 5055. The method of claim 5050, further comprising using aportion of the synthesis gas as a combustion fuel for the one or moreheat sources.
 5056. The method of claim 5035, wherein heating theselected section of the formation to a temperature to support reactionof hydrocarbon material in the formation to form synthesis gascomprises: introducing the O₂ rich stream into the formation through awellbore; transporting O₂ in the O₂ rich stream substantially byconvection into the portion of the selected section, wherein the portionof the selected section is at a temperature sufficient to support anoxidization reaction with O₂ in the O₂ rich stream; and reacting the O₂within the portion of the selected section to generate heat and raisethe temperature of the portion.
 5057. The method of claim 5056, whereinthe temperature sufficient to support an oxidization reaction with O₂ranges from approximately 200° C. to approximately 1200° C.
 5058. Themethod of claim 5056, wherein the one or more heat sources comprises oneor more electrical heaters disposed in the formation.
 5059. The methodof claim 5056, wherein the one or more heat sources comprises one ormore natural distributor combustors.
 5060. The method of claim 5056,wherein the one or more heat sources comprise one or more heater wells,wherein at least one heater well comprises a conduit disposed within theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 5061. The method of claim 5056, furthercomprising using a portion of the synthesis gas as a combustion fuel forthe one or more heat sources.
 5062. The method of claim 5035, furthercomprising controlling the heating of at least the portion of theselected section and provision of the synthesis gas generating fluid tomaintain a temperature within at least the portion of the selectedsection above the temperature sufficient to generate synthesis gas.5063. The method of claim 5035, wherein the synthesis gas generatingfluid comprises liquid water.
 5064. The method of claim 5035, whereinthe synthesis gas generating fluid comprises steam.
 5065. The method ofclaim 5035, wherein the synthesis gas generating fluid comprises waterand carbon dioxide, wherein the carbon dioxide inhibits production ofcarbon dioxide from the selected section.
 5066. The method of claim5065, wherein a portion of the carbon dioxide within the synthesis gasgenerating fluid comprises carbon dioxide removed from the formation.5067. The method of claim 5035, wherein the synthesis gas generatingfluid comprises carbon dioxide, and wherein a portion of the carbondioxide reacts with carbon in the formation to generate carbon monoxide.5068. The method of claim 5067, wherein a portion of the carbon dioxidewithin the synthesis gas generating fluid comprises carbon dioxideremoved from the formation.
 5069. The method of claim 5035, whereinproviding the synthesis gas generating fluid to at least the portion ofthe selected section comprises raising a water table of the formation toallow water to flow into the at least the portion of the selectedsection.
 5070. A method for producing ammonia using a coal formation,comprising: providing a first stream comprising N₂ and carbon dioxide tothe formation; allowing at least a portion of the carbon dioxide in thefirst stream to adsorb in the formation; producing a second stream fromthe formation, wherein the second stream comprises a lower percentage ofcarbon dioxide than the first stream; providing at least a portion ofthe N₂ in the second stream to an ammonia synthesis process.
 5071. Themethod of claim 5070, wherein the second stream comprises H₂ from theformation.
 5072. The method of claim 5070, wherein the first stream isproduced from the coal formation.
 5073. The method of claim 5072,wherein the first stream is generated by reacting a oxidizing fluid withhydrocarbon material in the formation.
 5074. The method of claim 5070,wherein the second stream comprises H₂ from the formation and, furthercomprising providing such H₂ to the ammonia synthesis process.
 5075. Themethod of claim 5070, further comprising using the ammonia synthesisprocess to generate ammonia.
 5076. The method of claim 5075, whereinfluids produced during pyrolysis of a coal formation comprise ammoniaand, further comprising adding at least a portion of such ammonia to theammonia generated from the ammonia synthesis process.
 5077. The methodof claim 5075, wherein fluids produced during pyrolysis of a coalformation are hydrotreated and at least some ammonia is produced duringhydrotreating, and further comprising adding at least a portion of suchammonia to the ammonia generated from the ammonia synthesis process.5078. The method of claim 5075, further comprising providing at least aportion of the ammonia to a urea synthesis process to produce urea.5079. The method of claim 5075, further comprising providing at least aportion of the ammonia to a urea synthesis process to produce urea and,further comprising providing carbon dioxide from the formation to theurea synthesis process.
 5080. The method of claim 5075, furthercomprising providing at least a portion of the ammonia to a ureasynthesis process to produce urea and further comprising shifting atleast a portion of carbon monoxide in the synthesis gas to carbondioxide in a shift process, and further comprising providing at least aportion of the carbon dioxide from the shift process to the ureasynthesis process.
 5081. A method for treating hydrocarbons in at leasta portion of a coal formation, wherein the portion has an averagepermeability of less than about 10 millidarcy, comprising: providingheat from one or more heat sources to the formation; allowing the heatto transfer from the one or more heat sources to a selected section ofthe formation such that heat from the heat sources pyrolyzes at leastsome hydrocarbons within the selected section, and wherein heat from theheat sources increases the permeability of at least a portion of theselected section; and producing a mixture comprising hydrocarbons fromthe formation.
 5082. The method of claim 5081, wherein the one or moreheat sources comprise at least two heat sources, and whereinsuperposition of heat from at least the two heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation,and wherein superposition of heat from at least the two heat sourcesincreases the permeability of at least the portion of the selectedsection.
 5083. The method of claim 5081, further comprising allowingheat to transfer from at least one of the one or more heat sources tothe selected section to create thermal fractures in the formationwherein the thermal fractures substantially increase the permeability ofthe selected section.
 5084. The method of claim 5081, wherein the heatis provided such that an average temperature in the selected sectionranges from approximately about 270° C. to about 400° C.
 5085. Themethod of claim 5081, wherein at least one of the one or more heatsources comprises an electrical heater located in the formation. 5086.The method of claim 5081, wherein at least one of the one or more heatsources is located in a heater well, and wherein at least one of theheater wells comprises a conduit located in the formation, and furthercomprising heating the conduit by flowing a hot fluid through theconduit.
 5087. The method of claim 5081, wherein at least some of theheat sources are arranged in a triangular pattern.
 5088. The method ofclaim 5081, further comprising: monitoring a composition of the producedmixture; and controlling a pressure in at least a portion of theformation to control the composition of the produced mixture.
 5089. Themethod of claim 5088, wherein the pressure is controlled by a valveproximate to a location where the mixture is produced.
 5090. The methodof claim 5088, wherein the pressure is controlled such that pressureproximate to the one or more heat sources is greater than a pressureproximate to a location where the fluid is produced.
 5091. A method fortreating hydrocarbons in at least a portion of a coal formation, whereinthe portion has an average permeability of less than about 10millidarcy, comprising: providing heat from one or more heat sources tothe formation; allowing the heat to transfer from the one or more heatsources to a selected section of the formation such that heat from theone or more heat sources pyrolyzes at least some hydrocarbons within theselected section, and wherein heat from the one or more heat sourcesvaporizes at least a portion of the hydrocarbons in the selectedsection; and producing a mixture comprising hydrocarbons from theformation.
 5092. The method of claim 5091, wherein the one or more heatsources comprise at least two heat sources, and wherein superposition ofheat from at least the two heat sources pyrolyzes at least somehydrocarbons within the selected section of the formation, and whereinsuperposition of heat from at least the two heat sources vaporizes atleast the portion of the hydrocarbons in the selected section.
 5093. Themethod of claim 5091, further comprising allowing heat to transfer fromat least one of the one or more heat sources to the selected section tocreate thermal fractures in the formation, wherein the thermal fracturessubstantially increase the permeability of the selected section. 5094.The method of claim 5091, wherein the heat is provided such that anaverage temperature in the selected section ranges from approximatelyabout 270° C. to about 400° C.
 5095. The method of claim 5091, whereinat least one of the one or more heat sources comprises an electricalheater located in the formation.
 5096. The method of claim 5091, whereinat least one of the one or more heat sources is located in a heaterwell, and wherein at least one of the heater wells comprises a conduitlocated in the formation, and further comprising heating the conduit byflowing a hot fluid through the conduit.
 5097. The method of claim 5091,wherein at least some of the heat sources are arranged in a triangularpattern.
 5098. The method of claim 5091, further comprising: monitoringa composition of the produced mixture; and controlling a pressure in atleast a portion of the formation to control the composition of theproduced mixture.
 5099. The method of claim 5098, wherein the pressureis controlled by a valve proximate to a location where the mixture isproduced.
 5100. The method of claim 5098, wherein the pressure iscontrolled such that pressure proximate to the one or more heat sourcesis greater than a pressure proximate to a location where the mixture isproduced.
 5101. A method for treating hydrocarbons in at least a portionof a coal formation, wherein the portion has an average permeability ofless than about 10 millidarcy, comprising: providing heat from one ormore heat sources to the formation, wherein at least one of the one ormore heat sources is located in a heater well; allowing the heat totransfer from the one or more heat sources to a selected section of theformation such that heat from the heat sources pyrolyzes at least somehydrocarbons within the selected section, and wherein heat from the heatsources pressurizes at least a portion of the selected section; andproducing a mixture comprising hydrocarbons from the formation, whereinthe mixture is produced from one or more of the heater sources. 5102.The method of claim 5101, wherein the one or more heat sources compriseat least two heat sources, and wherein superposition of heat from atleast the two heat sources pyrolyzes at least some hydrocarbons withinthe selected section of the formation.
 5103. The method of claim 5101,further comprising producing fluid from at least one of the one or moreheat sources.
 5104. The method of claim 5101, further comprisingallowing heat to transfer from at least one of the one or more heatsources to the selected section to create thermal fractures in theformation, wherein the thermal fractures substantially increase thepermeability of the selected section.
 5105. The method of claim 5101,wherein the heat is provided such that an average temperature in theselected section ranges from approximately about 270° C. to about 400°C.
 5106. The method of claim 5101, wherein at least one of the one ormore heat sources comprises an electrical heater located in theformation.
 5107. The method of claim 5101, wherein at least one of theone or more heat sources is located in a heater well, and wherein atleast one of the heater wells comprises a conduit located in theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 5108. The method of claim 5101, wherein atleast some of the heat sources are arranged in a triangular pattern.5109. The method of claim 5101, further comprising: monitoring acomposition of the produced mixture; and controlling a pressure in atleast a portion of the formation to control the composition of theproduced mixture.
 5110. The method of claim 5109, wherein the pressureis controlled by a valve proximate to a location where the mixture isproduced.
 5111. The method of claim 5109, wherein the pressure iscontrolled such that pressure proximate to the one or more heat sourcesis greater than a pressure proximate to a location where the mixture isproduced.
 5112. A method for treating hydrocarbons in at least a portionof a coal formation, wherein the portion has an average permeability ofless than about 10 millidarcy, comprising: providing heat from one ormore heat sources to the formation; allowing the heat to transfer fromthe one or more heat sources to a selected first section of theformation such that heat from the heat sources creates a pyrolysis zonewherein at least some hydrocarbons are pyrolyzed within the firstselected section, and allowing the heat to transfer from the one or moreheat sources to a selected second section of the formation such thatheat from the heat sources heats at least some hydrocarbons within theselected second section to a temperature less than the averagetemperature within the pyrolysis zone; and producing a mixturecomprising hydrocarbons from the formation.
 5113. The method of claim5112, wherein the one or more heat sources comprise at least two heatsources, and wherein superposition of heat from the at least two heatsources pyrolyzes at least some hydrocarbons within the selected firstsection of the formation, and wherein superposition of heat from the atleast two heat sources heats at least some hydrocarbons within theselected second section to a temperature less than the averagetemperature within the pyrolysis zone.
 5114. The method of claim 5112,wherein at least some heated hydrocarbons within the selected secondsection flow into the pyrolysis zone.
 5115. The method of claim 5112,wherein the heat decreases the viscosity of at least some of thehydrocarbons in the selected second section.
 5116. The method of claim5112, further comprising allowing heat to transfer from at least one ofthe one or more heat sources to the selected first section to createthermal fractures in the formation, wherein the thermal fracturessubstantially increase the permeability of the selected first section.5117. The method of claim 5112, further comprising allowing heat totransfer from at least one of the one or more heat sources to theselected second section to create thermal fractures in the formation,wherein the thermal fractures substantially increase the permeability ofthe selected second section.
 5118. The method of claim 5112, wherein theheat is provided such that an average temperature in the selected firstsection ranges from approximately about 270° C. to about 400° C. 5119.The method of claim 5112, wherein the heat is provided such that anaverage temperature in the selected second section ranges fromapproximately about 180° C. to about 250° C.
 5120. The method of claim5112, wherein a viscosity of at least some of the hydrocarbons in theselected second section ranges from approximately about 20 centipoise toabout 1000 centipoise.
 5121. The method of claim 5112, wherein at leastone of the one or more heat sources comprises an electrical heaterlocated in the formation.
 5122. The method of claim 5112, wherein atleast one of the one or more heat sources is located in a heater well,and wherein at least one of the heater wells comprises a conduit locatedin the formation, and further comprising heating the conduit by flowinga hot fluid through the conduit.
 5123. The method of claim 5112, furthercomprising: monitoring a composition of the produced mixture; andcontrolling a pressure in at least a portion of the formation to controlthe composition of the produced mixture.
 5124. The method of claim 5123,wherein the pressure is controlled by a valve proximate to a locationwhere the mixture is produced.
 5125. The method of claim 5123, whereinthe pressure is controlled such that pressure proximate to the one ormore heat sources is greater than a pressure proximate to a locationwhere the fluid is produced.
 5126. The method of claim 5122, wherein thepressure in the selected second section is substantially greater thanthe pressure in the selected first section.
 5127. The method of claim5112, wherein at least some of the heat sources are arranged in atriangular pattern.
 5128. The method of claim 5112, wherein an averagedistance between heat sources in the selected first section is less thanan average distance between heat sources in the selected second section.5129. The method of claim 5112, wherein the heat is provided to theselected first section before heat is provided to the selected secondsection.
 5130. The method of claim 5112, wherein the selected firstsection comprises at least one production well.
 5131. The method ofclaim 5112, wherein the selected first section comprises a planarregion.
 5132. The method of claim 5112, wherein at least one row of theheat sources provides heat to the planar region.
 5133. The method ofclaim 5112, wherein at least one ring comprising the heat sourcesprovides heat to the selected first section.
 5134. The method of claim5133, wherein at least one ring comprising the heat sources providesheat to the selected second section.
 5135. The method of claim 5133,wherein the ring comprises a polygon.
 5136. The method of claim 5133,wherein the ring comprises a regular polygon.
 5137. The method of claim5133, wherein the ring comprises a hexagon.
 5138. The method of claim5133, wherein the ring comprises a triangle.
 5139. A method for treatinghydrocarbons in at least a portion of a coal formation, wherein theportion has an average permeability of less than about 10 millidarcy,comprising: providing heat from three or more heat sources to theformation; allowing the heat to transfer from three or more of the heatsources to a selected section of the formation such that heat from theheat sources pyrolyzes at least some hydrocarbons within the selectedsection, and at least three of the heat sources are arranged in asubstantially triangular pattern; and producing a mixture comprisinghydrocarbons from the formation.
 5140. The method of claim 5139, whereinsuperposition of heat from at least the three heat sources pyrolyzes atleast some hydrocarbons within the selected section of the formation.5141. The method of claim 5139, wherein the mixture is produced from aproduction well located in a triangular region created by at least threeheat sources.
 5142. The method of claim 5139, further comprisingallowing heat to transfer from at least one of the one or more heatsources to the selected section to create thermal fractures in theformation, wherein the thermal fractures substantially increase thepermeability of the selected section.
 5143. The method of claim 5139,wherein the heat is provided such that an average temperature in theselected section ranges from approximately about 270° C. to about 400°C.
 5144. The method of claim 5139, wherein at least one of the one ormore heat sources comprises a electrical heater located in theformation.
 5145. The method of claim 5139, wherein at least one of theone or more heat sources is located in a heater well, and wherein atleast one of the heater wells comprises a conduit located in theformation, and further comprising heating the conduit by flowing a hotfluid through the conduit.
 5146. The method of claim 5139, wherein atleast some of the heat sources are arranged in a triangular pattern.5147. The method of claim 5139, further comprising: monitoring acomposition of the produced mixture; and controlling a pressure in atleast a portion of the formation to control the composition of theproduced mixture.
 5148. The method of claim 5147, wherein the pressureis controlled by a valve proximate to a location where the mixture isproduced.
 5149. The method of claim 5147, wherein the pressure iscontrolled such that pressure proximate to the one or more heat sourcesis greater than a pressure proximate to a location where the fluid isproduced.